MGE Energy (MGEE) 10-Q 3 Nov 16 2016 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2016	Oct. 31, 2016
Document And Entity Information [Line Items]
Entity Registrant Name	MGE Energy Inc
Entity Central Index Key	1,161,728
Document Type	10-Q
Document Period End Date	Sep. 30, 2016
Amendment Flag	false
Trading Symbol	MGEE
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Entity Well known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock Shares Outstanding		34,668,370
MGE [Member]
Document And Entity Information [Line Items]
Entity Registrant Name	Madison Gas and Electric Company
Entity Central Index Key	61,339
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Common Stock Shares Outstanding		17,347,894

MGE Energy Inc Consolidated Sta

MGE Energy Inc Consolidated Statements of Income (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Operating Revenues:
Electric revenues	$ 119,147	$ 123,364	$ 313,452	$ 325,027
Gas revenues	17,570	17,431	92,368	108,028
Total Operating Revenues	136,717	140,795	405,820	433,055
Operating Expenses:
Fuel for electric generation	20,505	17,055	47,567	41,624
Purchased power	9,167	18,484	38,698	62,614
Cost of gas sold	4,314	4,299	43,247	57,868
Other operations and maintenance	40,146	38,721	123,839	120,895
Depreciation and amortization	11,212	11,182	33,358	33,026
Other general taxes	4,846	4,877	14,841	14,951
Total Operating Expenses	90,190	94,618	301,550	330,978
Operating Income	46,527	46,177	104,270	102,077
Other income, net	2,105	2,564	6,726	7,115
Interest expense, net	(5,038)	(5,036)	(14,995)	(15,135)
Income before income taxes	43,594	43,705	96,001	94,057
Income tax provision	(15,714)	(15,351)	(34,943)	(33,946)
Net Income	$ 27,880	$ 28,354	$ 61,058	$ 60,111
Earnings Per Share of Common Stock (basic and diluted)	$ 0.80	$ 0.82	$ 1.76	$ 1.73
Dividends per share of common stock	$ 0.308	$ 0.295	$ 0.898	$ 0.860
Weighted Average Shares Outstanding (basic and diluted)	34,668	34,668	34,668	34,668

Madison Gas and Electric Compan

Madison Gas and Electric Company Consolidated Statements of Income (Unaudited) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Operating Revenues:
Electric revenues		$ 119,147	$ 123,364	$ 313,452	$ 325,027
Gas revenues		17,570	17,431	92,368	108,028
Total Operating Revenues		136,717	140,795	405,820	433,055
Operating Expenses:
Fuel for electric generation		20,505	17,055	47,567	41,624
Purchased power		9,167	18,484	38,698	62,614
Cost of gas sold		4,314	4,299	43,247	57,868
Other operations and maintenance		40,146	38,721	123,839	120,895
Depreciation and amortization		11,212	11,182	33,358	33,026
Other general taxes		4,846	4,877	14,841	14,951
Income tax provision		15,714	15,351	34,943	33,946
Total Operating Expenses		90,190	94,618	301,550	330,978
Operating Income		46,527	46,177	104,270	102,077
Other Income and Deductions:
Equity earnings in MGE Transco		2,023	2,398	6,023	6,568
Total Other Income and Deductions		2,105	2,564	6,726	7,115
Interest Expense:
Net Interest Expense		5,038	5,036	14,995	15,135
Net Income		27,880	28,354	61,058	60,111
MGE [Member]
Operating Revenues:
Electric revenues		119,152	123,371	313,470	325,044
Gas revenues		17,576	17,435	92,390	108,039
Total Operating Revenues		136,728	140,806	405,860	433,083
Operating Expenses:
Fuel for electric generation		20,507	17,057	47,574	41,630
Purchased power		9,171	18,488	38,709	62,624
Cost of gas sold		4,320	4,302	43,269	57,879
Other operations and maintenance		40,003	38,561	123,117	120,269
Depreciation and amortization		11,212	11,170	33,334	32,991
Other general taxes		4,846	4,877	14,841	14,951
Income tax provision		14,934	14,401	32,488	31,218
Total Operating Expenses		104,993	108,856	333,332	361,562
Operating Income	[1]	31,735	31,950	72,528	71,521
Other Income and Deductions:
AFUDC - equity funds		253	206	777	501
Equity earnings in MGE Transco		1,451	2,398	5,451	6,568
Income tax provision		(606)	(977)	(2,315)	(2,763)
Other income, net		(62)	(73)	(298)	(288)
Total Other Income and Deductions	[1]	1,036	1,554	3,615	4,018
Income before interest expense		32,771	33,504	76,143	75,539
Interest Expense:
Interest on long-term debt		5,079	5,123	15,284	15,410
Other interest, net		112	37	163	52
AFUDC - borrowed funds		(82)	(67)	(253)	(163)
Net Interest Expense		5,109	5,093	15,194	15,299
Net Income Including Noncontrolling Interest		27,662	28,411	60,949	60,240
Less Net Income Attributable to Noncontrolling Interest, net of tax		(5,695)	(6,633)	(17,899)	(19,812)
Net Income		$ 21,967	$ 21,778	$ 43,050	$ 40,428
[1]	Amounts are shown net of the related tax expense, consistent with the presentation on the MGE Consolidated Statement of Income.

MGE Energy Inc Consolidated St4

MGE Energy Inc Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Comprehensive Income [Abstract]
Net Income	$ 27,880	$ 28,354	$ 61,058	$ 60,111
Other comprehensive income, net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	11	(85)	(143)	(180)
Comprehensive Income	$ 27,891	$ 28,269	$ 60,915	$ 59,931

Madison Gas and Electric Compa5

Madison Gas and Electric Company Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Other comprehensive income, net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	$ 11	$ (85)	$ (143)	$ (180)
Comprehensive Income	27,891	28,269	60,915	59,931
MGE [Member]
Net Income	27,662	28,411	60,949	60,240
Other comprehensive income, net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	8	(28)	(31)	(137)
Total comprehensive income including noncontrolling interest	27,670	28,383	60,918	60,103
Less: Comprehensive income attributable to Noncontrolling Interest, net of tax	(5,695)	(6,633)	(17,899)	(19,812)
Comprehensive Income	$ 21,975	$ 21,750	$ 43,019	$ 40,291

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Unaudited) (Parantheticals) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Unrealized gain (loss) on available-for-sale securities, tax expense (benefit)	$ 8	$ (56)	$ (96)	$ (120)
MGE [Member]
Unrealized gain (loss) on available-for-sale securities, tax expense (benefit)	$ 5	$ (19)	$ (21)	$ (92)

MGE Energy Inc Consolidated St7

MGE Energy Inc Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Operating Activities:
Net Income	$ 61,058	$ 60,111
Items not affecting cash:
Depreciation and amortization	33,358	33,026
Deferred income taxes	15,041	7,370
Provision for doubtful receivables	583	(78)
Employee benefit plan expenses	165	2,500
Equity earnings in ATC	(6,023)	(6,568)
Other items	693	(154)
Changes in working capital items:
Decrease in current assets	33,740	39,034
Decrease in current liabilities	(3,147)	(18,231)
Dividend income from ATC	4,214	4,732
Cash contributions to pension and other postretirement plans	(13,134)	(12,460)
Other noncurrent items, net	2,644	13,373
Cash Provided by Operating Activities	129,192	122,655
Investing Activities:
Capital expenditures	(62,273)	(52,311)
Capital contributions to investments	(2,036)	(785)
Other	(310)	(85)
Cash Used for Investing Activities	(64,619)	(53,181)
Financing Activities:
Cash dividends paid on common stock	(31,115)	(29,816)
Repayment of long-term debt	(3,192)	(3,128)
Repayment of short-term debt	0	(7,000)
Other	(65)	(1,018)
Cash Used for Financing Activities	(34,372)	(40,962)
Change in cash and cash equivalents	30,201	28,512
Cash and cash equivalents at beginning of period	81,384	65,755
Cash and cash equivalents at end of period	111,585	94,267
Significant noncash investing activities:
Accrued capital expenditures	$ 10,603	$ 3,497

Madison Gas and Electric Compa8

Madison Gas and Electric Company Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Items not affecting cash:
Depreciation and amortization	$ 33,358	$ 33,026
Deferred income taxes	15,041	7,370
Provision for doubtful receivables	583	(78)
Employee benefit plan expenses	165	2,500
Equity earnings in MGE Transco	(6,023)	(6,568)
Other items	693	(154)
Changes in working capital items:
Decrease in current assets	33,740	39,034
Decrease in current liabilities	(3,147)	(18,231)
Dividend income from MGE Transco	4,214	4,732
Cash contributions to pension and other postretirement plans	(13,134)	(12,460)
Other noncurrent items, net	2,644	13,373
Cash Provided by Operating Activities	129,192	122,655
Investing Activities:
Capital expenditures	(62,273)	(52,311)
Capital contributions to investments	(2,036)	(785)
Other	(310)	(85)
Cash Used for Investing Activities	(64,619)	(53,181)
Financing Activities:
Repayment of long-term debt	(3,192)	(3,128)
Repayment of short-term debt	0	(7,000)
Other	(65)	(1,018)
Cash Used for Financing Activities	(34,372)	(40,962)
Change in cash and cash equivalents	30,201	28,512
Cash and cash equivalents at beginning of period	81,384	65,755
Cash and cash equivalents at end of period	111,585	94,267
Significant noncash investing activities:
Accrued capital expenditures	10,603	3,497
MGE [Member]
Operating Activities:
Net Income	60,949	60,240
Items not affecting cash:
Depreciation and amortization	33,334	32,991
Deferred income taxes	13,997	4,510
Provision for doubtful receivables	583	(78)
Employee benefit plan expenses	165	2,500
Equity earnings in MGE Transco	(5,451)	(6,568)
Other items	1,056	234
Changes in working capital items:
Decrease in current assets	32,557	46,806
Decrease in current liabilities	(1,783)	(15,876)
Dividend income from MGE Transco	4,214	4,732
Cash contributions to pension and other postretirement plans	(13,134)	(12,460)
Other noncurrent items, net	2,472	13,076
Cash Provided by Operating Activities	128,959	130,107
Investing Activities:
Capital expenditures	(62,273)	(52,311)
Capital contributions to investments	(1,598)	(533)
Other	(536)	(90)
Cash Used for Investing Activities	(64,407)	(52,934)
Financing Activities:
Cash dividends paid to parent by MGE	(40,000)	(20,000)
Distributions to parent from noncontrolling interest	(18,113)	(12,007)
Equity contribution received by noncontrolling interest	1,598	3,053
Repayment of long-term debt	(3,192)	(3,128)
Repayment of short-term debt	0	(7,000)
Other	(47)	(682)
Cash Used for Financing Activities	(59,754)	(39,764)
Change in cash and cash equivalents	4,798	37,409
Cash and cash equivalents at beginning of period	26,760	4,562
Cash and cash equivalents at end of period	31,558	41,971
Significant noncash investing activities:
Accrued capital expenditures	$ 10,603	$ 3,497

Consolidated Balance Sheets (Un

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Current Assets:
Cash and cash equivalents	$ 111,585	$ 81,384
Accounts receivable, less reserves	40,007	37,112
Other accounts receivables, less reserves	6,885	7,477
Unbilled revenues	13,885	25,008
Materials and supplies, at average cost	20,004	19,155
Fossil fuel, at average cost	9,113	13,110
Stored natural gas, at average cost	14,886	16,145
Prepaid taxes	12,617	35,252
Regulatory assets - current	7,207	9,538
Other current assets	13,115	10,570
Total Current Assets	249,304	254,751
Regulatory assets	146,305	148,199
Other deferred assets and other	6,361	6,377
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,243,081	1,217,094
Construction work in progress	38,290	26,351
Total Property, Plant, and Equipment	1,281,371	1,243,445
Investments	76,731	73,631
Total Assets	1,760,072	1,726,403
Current Liabilities:
Long-term debt due within one year	4,333	4,266
Accounts payable	49,961	40,830
Accrued interest and taxes	4,538	5,067
Accrued payroll related items	9,783	11,215
Regulatory liabilities - current	3,564	9,515
Derivative liabilities	8,030	8,343
Other current liabilities	5,950	4,910
Total Current Liabilities	86,159	84,146
Other Credits:
Deferred income taxes	376,194	360,785
Investment tax credit - deferred	973	1,050
Regulatory liabilities	21,959	20,785
Accrued pension and other postretirement benefits	61,825	75,680
Derivative liabilities	42,460	44,935
Other deferred liabilities and other	66,450	61,820
Total Other Credits	569,861	565,055
Capitalization:
Common shareholders equity	720,258	690,458
Long-term debt	383,794	386,744
Total Capitalization	1,104,052	1,077,202
Commitments and contingencies (see Footnote 7)
Total Liabilities and Capitalization	1,760,072	1,726,403
MGE [Member]
Current Assets:
Cash and cash equivalents	31,558	26,760
Accounts receivable, less reserves	40,007	37,112
Affiliate receivables	565	542
Other accounts receivables, less reserves	6,816	7,390
Unbilled revenues	13,885	25,008
Materials and supplies, at average cost	20,004	19,155
Fossil fuel, at average cost	9,113	13,110
Stored natural gas, at average cost	14,886	16,145
Prepaid taxes	12,793	34,279
Regulatory assets - current	7,207	9,538
Other current assets	13,082	10,544
Total Current Assets	169,916	199,583
Affiliate receivable long-term	4,369	4,766
Regulatory assets	146,305	148,199
Other deferred assets and other	4,100	4,216
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,242,459	1,216,415
Construction work in progress	38,290	26,351
Total Property, Plant, and Equipment	1,280,749	1,242,766
Investments	47,259	69,984
Total Assets	1,652,698	1,669,514
Current Liabilities:
Long-term debt due within one year	4,333	4,266
Accounts payable	49,949	40,742
Accrued interest and taxes	5,710	5,021
Accrued payroll related items	9,783	11,215
Regulatory liabilities - current	3,564	9,515
Derivative liabilities	8,030	8,343
Other current liabilities	5,901	4,791
Total Current Liabilities	87,270	83,893
Other Credits:
Deferred income taxes	367,066	352,626
Investment tax credit - deferred	973	1,050
Regulatory liabilities	21,959	20,785
Accrued pension and other postretirement benefits	61,825	75,680
Derivative liabilities	42,460	44,935
Other deferred liabilities and other	66,450	61,817
Total Other Credits	560,733	556,893
Capitalization:
Common shareholders equity	504,695	501,676
Noncontrolling interest	116,206	140,308
Total Equity	620,901	641,984
Long-term debt	383,794	386,744
Total Capitalization	1,004,695	1,028,728
Commitments and contingencies (see Footnote 7)
Total Liabilities and Capitalization	$ 1,652,698	$ 1,669,514

Consolidated Balance Sheets (10

Consolidated Balance Sheets (Unaudited) (Parentheticals) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Receivables, Net
Reserve for uncollectible accounts receivable	$ 2,815	$ 3,052
Reserve for uncollectible other accounts receivable	480	642
MGE [Member]
Receivables, Net
Reserve for uncollectible accounts receivable	2,815	3,052
Reserve for uncollectible other accounts receivable	$ 480	$ 642

MGE Energy Inc Consolidated S11

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 [Member]
Beginning balance, shares at Dec. 31, 2014		34,668
Beginning balance, value before adjustments at Dec. 31, 2014	$ 659,401			$ 308,007
Cumulative effect of new accounting principle at Dec. 31, 2014	(142)			(142)
Beginning balance, value at Dec. 31, 2014	659,259	$ 34,668	$ 316,268	307,865	$ 458
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	60,111			60,111
Other comprehensive loss	(180)				(180)
Common stock dividends declared	(29,816)			(29,816)
Ending balance, shares at Sep. 30, 2015		34,668
Ending balance, value at Sep. 30, 2015	689,374	$ 34,668	316,268	338,160	278
Beginning balance, shares at Dec. 31, 2015		34,668
Beginning balance, value at Dec. 31, 2015	690,458	$ 34,668	316,268	339,165	357
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	61,058			61,058
Other comprehensive loss	(143)				(143)
Common stock dividends declared	(31,115)			(31,115)
Ending balance, shares at Sep. 30, 2016		34,668
Ending balance, value at Sep. 30, 2016	$ 720,258	$ 34,668	$ 316,268	$ 369,108	$ 214

Madison Gas and Electric Comp12

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]
Beginning balance, shares at Dec. 31, 2014			34,668	17,348
Beginning balance, value before adjustments at Dec. 31, 2014		$ 612,260					$ 276,662
Cumulative effect of new accounting principle at Dec. 31, 2014	$ (142)	(142)				$ (142)	(142)
Beginning balance, value at Dec. 31, 2014		612,118		$ 17,348	$ 192,417		276,520		$ 144	$ 125,689
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income		60,240					40,428			19,812
Other comprehensive loss	(180)	(137)						$ (180)	(137)
Cash dividends paid to parent by MGE		(20,000)					(20,000)
Equity contribution received by noncontrolling interest		3,053								3,053
Distributions to parent from noncontrolling interest		(12,007)								(12,007)
Ending balance, shares at Sep. 30, 2015			34,668	17,348
Ending balance, value at Sep. 30, 2015		643,267		$ 17,348	192,417		296,948		7	136,547
Beginning balance, shares at Dec. 31, 2015			34,668	17,348
Beginning balance, value at Dec. 31, 2015		641,984		$ 17,348	192,417		291,888		23	140,308
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income		60,949					43,050			17,899
Other comprehensive loss	$ (143)	(31)						$ (143)	(31)
Cash dividends paid to parent by MGE		(40,000)					(40,000)
Equity contribution received by noncontrolling interest		1,598								1,598
Distributions to parent from noncontrolling interest		(18,113)								(18,113)
Deconsolidation of noncontrolling interest		(25,486)								(25,486)
Ending balance, shares at Sep. 30, 2016			34,668	17,348
Ending balance, value at Sep. 30, 2016		$ 620,901		$ 17,348	$ 192,417		$ 294,938		$ (8)	$ 116,206

Consolidated Statements of Comm

Consolidated Statements of Common Equity (Unaudited) (Parentheticals) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Consolidated Statements of Common Equity
Dividends per share of common stock	$ 0.308	$ 0.295	$ 0.898	$ 0.860

Basis of Presentation

Basis of Presentation	9 Months Ended
	Sep. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation	Basis of Presentation - MGE Energy and MGE . 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. B oth 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 2 of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy ' s and MGE ' s 2015 Annual Report on Form 10-K. MGE Transco is jointly owned by MGE Energy and MGE. M GE ' s ownership interest in MGE Transco declined below a majority in July 2016. As a result of the change in majority ownership in MGE Transco in July 2016, MGE deconsolidated MGE Energy ' s proportionate share of the equity in MGE Transco. The change in cons olidation was applied prospectively by reducing its investment and noncontrolling interest on MGE ' s consolidated financial statements. See Footnote 3 for further discussion . The accompanying consolidated financial statements as of September 30, 2016 , 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 MGE Energy's and MGE's 2015 Annual Report on Form 10-K, but does not include all disclosures required by accounting principles generally accepted in the Unite d States of America. Th ese notes should be read in conjunction with the financial statements and the notes on pages 55 through 1 05 of the 2015 Annual Report on Form 10-K .

Equity and Financing Arrangemen

Equity and Financing Arrangements	9 Months Ended
	Sep. 30, 2016
Equity and Financing Arrangements Disclosure [Abstract]
Equity and Financing Arrangements	Equity and Financing Arrangements - MGE Energy. a. 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. For both the nine months ended September 30, 2016 and 2015 , MGE Energy did not issue any new shares of common st ock under the Stock Plan. b. Dilutive Shares Calculation. MGE Energy does not have any dilutive securities. c. Long-term Debt - MGE Energy and MGE. MGE has $30 million of medium-term notes maturing in 2017. MGE priced $40 million of new long-term unsecured debt in October 2016, with funding expected to occur in mid-January 2017. The new debt will carry an interest rate of 3.76% per annum over its 35-year term. The proceeds of this debt financing will be used to refinance the maturing $30 million medium-term notes and assist with the financing of additional capital expenditures. The covenants of this debt ar e expected to be substantially consistent with MGE ' s existing unsecured long-term debt. In accordance with applicable accounting guidance, MGE has classified the $30 million of maturing medium-term notes as long-term debt on the consolidated balance sheets for the quarter ended September 30, 2016.

Investment in ATC

Investment in ATC	9 Months Ended
	Sep. 30, 2016
Equity Method Investments and Joint Ventures [Abstract]
Investment in ATC	Investment in ATC - 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 is jointly owned by MGE Energy and MGE. MGE Transco has accounted for its investment in ATC under the equity method of accounting. For the three and nine months ended September 30, 2016 and 2015 , MGE Transco recorded the following : Three Months Ended Nine Months Ended September 30, September 30, (In thousands) 2016 2015 2016 2015 Equity earnings from investment in ATC $ 2,023 $ 2,398 $ 6,023 $ 6,568 Dividends received from ATC 1,486 1,841 4,214 4,732 Capital contributions to ATC 888 177 1,598 533 MGE Transco ' s investment in ATC as of September 30, 2016 , and December 31, 2015 , was $ 72.9 million and $ 69.5 million, respectively. As of September 30, 2016 , MGE ' s investment in MGE Transco was $ 46.8 million. At September 30, 2016 , MGE Energy, the holding company, is the majority owner ( 50.5 %), and MGE is the minority owner ( 49.5 %) of MGE Transco. MGE ' s ownership intere st declined below a majority in July 2016 as a result of continued funding of ATC capital contributions by MGE Energy. As a result of the change in majority ownership in MGE Transco in July 2016, MGE deconsolidate d MGE Energy ' s proportionate share of the e quity in MGE Transco. The change in consolidation was applied prospectively by reducing its investment and noncontrolling interest on MGE ' s consol idated financial sta tements. No gain or loss was recognized in July 2016 due to MGE ceasing to have a controll ing financial interest. As of December 31, 2015 , the noncontrolling interest on MGE ' s consolidated balance sheets was $ 23.6 million. For the three and nine months ended September 30, 2016 and 2015 , MGE recorded the following amounts attributable to noncontrolling interest in MGE Transco: Three Months Ended Nine Months Ended September 30, September 30, (In thousands) 2016 2015 2016 2015 Equity earnings from investment (a) $ 254 $ 679 $ 1,410 $ 1,848 Dividends received from investment (a) 561 423 1,113 1,007 Capital contributions by noncontrolling interest 888 177 1,598 533 (a ) Amounts reflected net of tax. In June 2016, the PSCW accepted a staff recommendation to have MGE transfer its interest in ATC to MGE Energy. As a result, MGE ' s ownership interest in MGE Transco will be completely eliminated in favor of MGE Energy when the transfers are complete, which is required by December 31, 2022. The recommendation arose in the context of requests for regulatory approvals by several owners of ATC in connection with a reorganization of ATC designed to separate its existing Wisc onsin-based transmission operations from its non-Wisconsin transmission development activities. The change will have no effect on MGE Energy's consolidated financial statements. ATC ' s summarized financial data for the three and nine months ended September 30, 2016 an d 2015 , is as follows: Three Months Ended Nine Months Ended September 30, September 30, (In thousands) 2016 2015 2016 2015 Operating revenues $ 158,126 $ 164,515 $ 476,591 $ 482,043 Operating expenses (80,271) (78,059) (241,034) (238,336) Other income, net 1,128 585 2,563 566 Interest expense, net (24,624) (23,655) (73,714) (72,310) Earnings before members' income taxes $ 54,359 $ 63,386 $ 164,406 $ 171,963 MGE receives transmission and other related services from ATC. During the three and nine months ended September 30, 2016 , MGE recorded $ 7.4 million and $ 22.1 million, respectively, for transmission services received compared to $ 7.0 million and $ 21.1 million for the comparable periods in 2015 . MGE also provides a variety of operational, maintenance, and project management services for ATC, which is reimbursed by ATC. As of September 30, 2016 and December 31, 2015 , MGE had a receivable due from ATC of $ 0.3 million and $ 0.2 million, respectively.

Taxes

Taxes	9 Months Ended
	Sep. 30, 2016
Income Tax Disclosure [Abstract]
Taxes	Taxes - MGE Energy and MGE . MGE Ene rgy's effective income tax rates for the three and nine months ended September 30, 2016 , were 36.1 % and 36.4 %, respectively, compared to 35.1 % and 36.1 % for the same periods in 2015 . MGE's effective income tax rates for the three and nine months ended September 30, 2016 , were 36.0 % and 36.4 %, respectively, compared to 35.1 % and 36.1 % for the same periods i n 2015 . The increase in the effective tax rates is due in part to a lower estimated domestic manufacturing deduction offset by higher estimated AFUDC equity earnings in 2016.

Pension and Other Postretiremen

Pension and Other Postretirement Plans	9 Months Ended
	Sep. 30, 2016
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 def ined contribution 401(k) benefit plans. MGE refined its methodology for using discount rates to measure the components of net periodic benefit cost for 2016. The refined methodology uses individual spot rates, instead of a weighted average of the yield curve spot rates, for measuring the service cost and interest cost com ponents. The following table presents the components of MGE Energy's and MGE's net periodic benefit costs recognized for the three and nine months ended September 30, 2016 and 2015 . A portion of the net periodic benefit cost is capitalized within the consolidated b alance sheets. Three Months Ended Nine Months Ended September 30, September 30, (In thousands) 2016 2015 2016 2015 Pension Benefits Components of net periodic cost: Service cost $ 1,413 $ 1,878 $ 4,358 $ 5,715 Interest cost 3,161 3,594 9,744 10,936 Expected return on assets (5,724) (5,930) (17,646) (18,045) Amortization of: Prior service cost 3 6 8 18 Actuarial loss 1,388 1,393 4,278 4,240 Net periodic cost $ 241 $ 941 $ 742 $ 2,864 Postretirement Benefits Components of net periodic (benefit) cost: Service cost $ 361 $ 194 $ 1,084 $ 580 Interest cost 753 392 2,258 1,176 Expected return on assets (787) (355) (2,360) (1,063) Amortization of: Transition obligation 1 - 3 1 Prior service benefit (744) (337) (2,233) (1,009) Actuarial loss 178 133 533 397 Net periodic (benefit) cost $ (238) $ 27 $ (715) $ 82

Share-Based Compensation

Share-Based Compensation	9 Months Ended
	Sep. 30, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Share-Based Compensation	Share-Based Compensation - MGE Energy and MGE. Under MGE Energy ' s Performance Unit Plan and the Director Incentive Plan, eligible employees and non-employee directors 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 set performance period. In Jan uary 2016 , 3,773 units were granted under the Director Incentive Plan and are subject to a three-year graded vesting schedule . In February 2016 , 19,055 units were gr anted under the Performance Unit Plan and are subject to a five-year graded vesting schedule. On the grant d ate, MGE Energy and MGE measure the cost of the employee services received in exchange for a performance unit award based on the current market valu e of MGE Energy common stock. The fair value of the awards is re-measured quarterly, including at September 30, 2016 , as required by applicable accounting standards. Changes in fair value as well as the original grant are recognized as compensation cost. Si nce this amount is re-measured 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 grade d 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. During the three and nine months ended September 30, 2016 , MGE recorded $ 0.2 million and $ 2.0 million, respectively, in compensation expense as a result of awards under the plans compared to $ 0.3 million and $ 0.4 million for the comparable periods in 2015 . In January 2016 , cash payments of $ 1.2 million were distributed relating to awards that were granted in 2011. During the nine months ended September 30, 2015 , MGE recorded a $ 0.2 million gain on 4,676 units forfeited. No forfeitures occurred during the nine months ended September 30, 2016 . At September 30, 2016 , $ 5.8 million of outstanding awards are vested, and of this amount, no cash settlements have occurred.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies - MGE Energy and MGE . a. Environmental. 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 we conduct our operations, the costs of those operations, as well as capital and operating expenditures. Regulatory initiatives, proposed rules, and court challenges to adopted rules, have the potential to have a material effect on our capital expenditures and operating costs. These initiatives, proposed rules, and court challenges include: EPA's Effluent Limitations Guidelines (ELG) and Standards for Steam Electric Power Generating Point Source Category In November 2015, the EPA published its final rule setting Effluent Limitations Guidelines (ELG) for the steam electric power generating industry. The ELG rule establishes federal limits on the amount of met als and other pollutants that can be discharged in wastewater from new and existing steam electric generation plants. The ELG rule mostly covers pollutants that are captured by certain air pollution control systems and via wet ash handling systems at coal- burning power plants with units greater than 50 MW generation capacity. The operators of our Columbia and Elm Road Units have indicated that equipment upgrades may be necessary to comply with the new discharge standards. The rule will be applied to Wiscons in-based power plants as they renew their WPDES permits, beginning in 2018 but no later than 2023. Management believes that any compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects. EPA Coolin g Water Intake Rules (Section 316(b)) Section 316(b) of the Clean Water Act requires that the cooling water intake structures at electric power plants 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. The EPA finalized its 316(b) rule for existing facilities in 2014. Section 316(b) requirements are implemented in Wisconsin through modifications to plants' WPDES permi ts, which govern plant wastewater discharges. WDNR is currently developing rules to implement the EPA 316(b) rule. Our WCCF, Blount, and Columbia plants are considered existing plants under this rule. Our WCCF facility already employs a system that meets the 316(b) rule. Our Blount plant has conducted studies showing that it will likely be in compliance with this rule when its WPDES permit is renewed in 2017. The operator of our Columbia plant is conducting an intake study to demonstrate compliance with t he 316(b) rule and/or identify design criteria needed to meet the new rule requirements prior to Columbia's 2017 WPDES permit renewal. The exact requirements at Blount and Columbia, however, will not be known until the WDNR finalizes its rule, approves the plant operators' approach, and those sites' WPDES permits are modified to account for this rule. Nonetheless, MGE expects that the 316(b) rule will not have material effects on its existing plants. EPA's Greenhouse Gas (GHG) Reduction Guidelines under the Clean Air Act 111(d) Rule In October 2015, the EPA published its Clean Power Plan (CPP) rule with an effective date of December 2015, setting guidelines and approval criteria for states to use in developing plans to control GHG emissions from existing fossil fuel-fired electric generating units (EGUs) and systems. In October 2015, the EPA also published a proposed federal implementation plan under the CPP rule. The proposed federal implementation plan is designed to provide mass-based and rate-based emi ssions trading options to serve as a model and/or resource for states that are adopting their own plans, or for use by the EPA in states that do not implement their own plans under the finalized CPP. Implementation of the rule is expected to have a direct impact on existing coal and natural gas fired generating units, including possible changes in dispatch and additional operating costs. On February 9, 2016, the U.S. Supreme Court issued a stay blocking implementation of the CPP pending the Court ' s own rev iew. The CPP may not be implemented until the Supreme Court lifts the stay, presumably after the courts ultimately resolve the underlying legality of the rule. Oral arguments were held before the D.C. Circuit on September 27, 2016 and a decision by the D.C. Circuit is expecte d in 2017. Given the pending legal proceedings and the need for a yet-to-be-developed state implementation plan or finalization of the federal implementation plan, the nature and timing of any final requirements is subject to uncertainty. If the rule rema ins substantially in its present form, it is expected to have a material impact on MGE. National Ambient Air Quality Standards (NAAQS) The EPA's NAAQS regulations set ambient levels of six pollutants to protect sensitive populations (primary NAAQS) and the environment (secondary NAAQS) from the negative effects of exposure to these pollutants at higher levels. MGE is following EPA's efforts to update several NAAQS, including for particulate matter, nitrogen dioxide, sulfur dioxide, and ozone. Further dis cussion on ozone, sulfur dioxide, and nitrogen dioxide NAAQS follows. For additional information on the NAAQS process, see Footnote 18.c. of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy 's and MGE's 2015 Annual Report on Form 10-K. Ozone NAAQS In October 2015, the EPA revised the primary and secondary ozone NAAQS, lowering each to 70 ppb. The rule became effective in December 2015. Based on current ozone monitoring data, it appears that Milwaukee County (where our Elm Road Units are located) will likely not attain the lowered standards, and Dane and Columbia Counties (where our WCCF/Blount and Columbia Units are located, respectively) may attain them. Final attainment designations for th ese three counties will be based upon air monitoring data for years 2014-2016. The EPA will finalize the designations by October 1, 2017 based on air monitoring data for the years 2014-2016. Once these EPA designations are complete, the State of Wisconsin will need to develop implementation plans for each county designated as nonattainment, which could affect operations and emission control obligations for plants located within the nonattainment counties. The State of Wisconsin has joined a lawsuit filed by several states challenging the EPA's new ozone standard, alleging that the new standard is not attainable and the EPA is not properly considering background levels in setting its ozone attainment levels. MGE will continue to monitor the EPA's progress on attainment designations and related litigation to assess potential impacts at our facilities, particularly our Elm Road Units. Sulfur Dioxide (SO 2 ) NAAQS In March 2015, the EPA identified MGE's Columbia Plant in Columbia County as a large stationary sourc e of SO 2 that may exceed the one hour SO 2 NAAQS standard and was subject to a State of Wisconsin proposed county attainment/nonattainment determination. In September 2015, Wisconsin sent a letter to the EPA proposing that Columbia County be designated as b eing in attainment for the SO 2 NAAQS based on recent modeling demonstrating that SO 2 pollution controls on the Columbia Plant had brought the county into attainment. In June 2016, the EPA issued a final rule classifying Columbia County as an unclassified/a ttainment area. In addition to the EPA's actions on the SO 2 NAAQS, the WDNR has revised its state rules to incorporate the one hour SO 2 standard. MGE does not anticipate any material costs from this rule. Nitrogen Dioxide (NO 2 ) NAAQS The WDNR has revised its state rules to incorporate the EPA's one hour NO 2 NAAQS rule that was finalized in 2010. The effective date of the state rule was August 1, 2016. The WDNR is currently seeking input from the public on ideas for implementing this one-hour standard. Wisc onsin's NO 2 NAAQS rule will affect our stationary fossil-fuel generation sources by requiring that we demonstrate consistency with the NAAQS when applying for certain air permits. Sources that cannot demonstrate compliance with the NAAQS may be required to install emission controls or restrict operations. MGE will continue to monitor developments while the WDNR implements guidance for compliance with the one-hour NAAQS. EPA's Cross-State Air Pollution Rule: Proposed Ozone Season Update based on 2008 Ozon e NAAQS The EPA's Cross-State Air Pollution Rule (CSAPR) is an interstate air pollution transport rule designed to reduce ozone and fine particulate (PM2.5) air levels in areas that the EPA has determined are being affected by pollution from neighboring an d upwind states. This is accomplished in the CSAPR through a reduction in SO 2 and Nitrogen Oxides (NO x ) from fossil-fuel fired power plants. NO x and SO 2 contribute to fine particulate pollution, and NO x contributes to ozone formation. Reductions are achiev ed through a cap and trade system. Individual plants can meet their caps through modifications and/or buying allowances on the market. In October 2016, the EPA finalized an update to the existing CSAPR. The CSAPR Rule Update is designed to incorporate 200 8 Ozone NAAQS attainment levels (the original CSAPR is based on 1997 Ozone NAAQS levels) in 22 states, including Wisconsin, by further limiting ozone season NO x levels through a reduction in NO x allowances. The rule also includes revisions to CSAPR that ar e designed to address issues remaining from the D.C. Circuit remand of CSAPR, including Wisconsin's inclusion in the NO x ozone season portion of the rule. The rule will further reduce summertime (or Ozone Season) NO x emissions from power plants starting in 2017. Initial review of this rule shows that we will likely need to buy NO x Ozone Season allowances to comply with the rule. MGE is still evaluating the impact of this final rule on our operations, and we are unable to determine the full extent of the r ule's impacts at this time. Depending on the cost of allowances, this requirement could be material for MGE. Clean Air Visibility Rule (CAVR) Columbia may be subject to the best available retrofit technology (BART) regulations, a subsection of the EPA's Clean Air Visibility Rule (CAVR), which may require pollution control retrofits. Columbia's 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. In February 2016, the EPA submitted a proposed revision to the CAVR. The proposed revision would move state plan due dates from July 2018 to July 2021. This would allow for states to coordinate their CAVR compliance with oth er compliance efforts. If this proposed revision is finalized, it would reduce the chances that CAVR would be material for MGE. At this time, however, the BART regulatory obligations, compliance strategies, and costs remain uncertain due to the continued l egal challenges surrounding CSAPR and CAVR. Solid Waste EPA's Coal Combustion Residuals Rule In December 2014, the EPA finalized its Disposal of Coal Combustion Residuals from Electric Utilities (CCR) rule. The rule became effective in October 2015. It p rovides that coal ash will be regulated as a solid waste, and defines what ash use activities would be considered generally exempt beneficial reuse of coal ash. The rule also regulates landfills, ash ponds, and other surface impoundments for coal combustio n residuals by regulating their design, location, monitoring, and operation. This portion of the rule is accomplished in phases to allow for sites with onsite storage and/or disposal to evaluate their compliance with the rule's design criteria. Landfills a nd impoundments that cannot meet design criteria will need to close formally within defined timeframes. The Columbia and Elm Road Units co-owners and plant operators are working through the phased requirements to plan and implement changes necessary at th ose facilities to meet design criteria. Review of our Elm Road facility has indicated that the costs to comply with this rule are not expected to be significant. Columbia's operator has developed a preliminary implementation schedule for meeting the variou s deadlines spelled out in the rule. Costs at Columbia will be dependent on what is determined during the evaluation stage. Management believes compliance costs will be recovered in future rates based on previous treatment of environmental compliance proj ects. b. Legal Matters. 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 have entered into various commodity supply, transportation, and storage contracts to meet their obligations to deliver electricity and natural gas to customers. As of September 30, 2016 , the future commitments related to these purchase contracts were as follows: (In thousands) 2016 2017 2018 2019 2020 Thereafter Coal (a) $ 23,260 $ 16,535 $ 12,640 $ 3,850 $ - $ - Natural gas Transportation & storage (b) 6,005 20,858 20,644 19,482 15,225 31,767 Supply (c) 11,661 12,580 - - - - $ 40,926 $ 49,973 $ 33,284 $ 23,332 $ 15,225 $ 31,767 (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. If any minimum purchase obligations must be paid under these contracts, management believes these obligations would be considered costs of service and recoverable in rates. (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. Management expects to recover these costs in future customer rates . (c) These commitments include market-based pricing. Management expects to recover these costs in future customer rates .

Derivative and Hedging Instrume

Derivative and Hedging Instruments	9 Months Ended
	Sep. 30, 2016
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, MGE Energy and MGE recognize such derivatives in the co nsolidated 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 st rategies. 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 regulato ry asset or liability. 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 electri c rates as a component of the fuel rules mechanism. b. Notional Amounts. The gross notional volume of open derivatives is as follows: September 30, 2016 December 31, 2015 Commodity derivative contracts 465,835 MWh 355,580 MWh Commodity derivative contracts 6,157,500 Dth 5,037,500 Dth FTRs 3,567 MW 2,000 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 FTRs. An FTR is a financial instrument th at entitles the holder to a stream of revenues or charges based on the differences in hourly day-ahead energy prices between two p oints on the transmission grid. The fair values of these instruments are offset with a corresponding regulatory asset/liabilit y 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 t he delivery month applicable to the instrument. At September 30, 2016 , the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $ 0.9 million. At December 31 , 2015 , the cost basis of exchange traded deriv atives and FTRs exceeded their fair value by $ 0.8 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 sheet s . 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 at September 30, 2016 , and December 31, 2015 , reflects a loss position of $ 50.5 million and $ 53.3 million, respectively. The actual cost will be recognized in purchased power e xpense in the month of purchase. The following table summarizes the fair value of the derivative instruments on the consolidat ed balance sheet s . 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 collatera l. For financia l statement purposes, MGE Energy and MGE have netted instruments with the same counterparty under a master netting agreement as well as the netting of collatera l. As of September 30, 2016 and December 31, 2015 , MGE Energy and MGE had a receivable – marg in account balance of $ 1.6 million and $ 2.3 million, respectively, which is shown net of any collateral posted against derivative positions . Asset Derivatives Liability Derivatives (In thousands) Balance Sheet Location Fair Value Balance Sheet Location Fair Value September 30, 2016 Commodity derivative contracts Other current assets $ 1,023 Derivative liability (current) $ 351 Commodity derivative contracts Other deferred charges 114 Derivative liability (long-term) 97 FTRs Other current assets 230 Derivative liability (current) - PPA N/A N/A Derivative liability (current) 8,030 PPA N/A N/A Derivative liability (long-term) 42,460 December 31, 2015 Commodity derivative contracts Other current assets $ 146 Derivative liability (current) $ 1,266 Commodity derivative contracts Other deferred charges 144 Derivative liability (long-term) 70 FTRs Other current assets 234 Derivative liability (current) - PPA N/A N/A Derivative liability (current) 8,340 PPA N/A N/A Derivative liability (long-term) 44,930 The foll owing tables show the ef fect of netting arrangements for recognized derivative assets and liabilities that are subject to a master netting arr angement 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, 2016 Commodity derivative contracts $ 1,137 $ (448) $ - $ 689 FTRs 230 - - 230 December 31, 2015 Commodity derivative contracts $ 290 $ (290) $ - $ - FTRs 234 - - 234 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, 2016 Commodity derivative contracts $ 448 $ (448) $ - $ - PPA 50,490 - - 50,490 December 31, 2015 Commodity derivative contracts $ 1,336 $ (290) $ (1,038) $ 8 PPA 53,270 - - 53,270 The following table s summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheet s at September 30, 2016 and 2015 , and the consolidated income statement s for the three and nine months ended September 30, 2016 and 2015 . 2016 2015 (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, $ 50,521 $ 659 $ 56,048 $ 455 Unrealized (gain) loss (663) - 4,036 - Realized gain (loss) reclassified to a deferred account 17 (17) (408) 408 Realized (loss) gain reclassified to income statement (304) 46 (2,278) (91) Balance at September 30, $ 49,571 $ 688 $ 57,398 $ 772 Nine Months Ended September 30: Balance at January 1, $ 54,082 $ 1,208 $ 54,998 $ 1,001 Unrealized loss 1,128 - 8,514 - Realized (loss) gain reclassified to a deferred account (1,417) 1,417 (1,700) 1,700 Realized (loss) gain reclassified to income statement (4,222) (1,937) (4,414) (1,929) Balance at September 30, $ 49,571 $ 688 $ 57,398 $ 772 Realized Losses (Gains) 2016 2015 (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 $ 45 $ - $ 862 $ (17) FTRs (703) - (233) - PPA 916 - 1,757 - Nine Months Ended September 30: Commodity derivative contracts $ 1,469 $ 1,814 $ 1,860 $ 1,742 FTRs (635) - (607) - PPA 3,511 - 3,348 - MGE's commodity derivativ e 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 sheet s 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, 2016 , 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 pos ted. As of September 30, 2016 , no counterparties were in a net liability position. As of December 31, 2015 , certain counterparties were in a net liability position of less than $ 0.1 million. 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 mitig ate nonperformance risk in its portfolio. As of September 30, 2016 , no counterparties have defaulted.

Rate Matters

Rate Matters	9 Months Ended
	Sep. 30, 2016
Regulated Operations [Abstract]
Rate Matters	Rate Matters - MGE Energy and MGE. a. Rate P roceedings. I n April 2016, MGE filed an application with the PSCW requesting a 1.7 % increase to electric rates and a 3.7 % increase to gas rates for 2017. The proposed electric and gas rate increases cover costs primarily associated with the state ' s electric transmission and MGE ' s natural gas system infrastructure improvements . In July 2015 , the PSCW approved MGE ' s request to extend the current accounting treatment for transmission related costs through 2016, conditioned upon MGE not filing a base rate case for 2016 . This accounting treatment allow s MGE to reflect any differential between transmission costs reflected in rate s and actual costs incurred in its next rate case filing, which occurred as part of the April 2016 filing. On December 23, 2014, the PSCW authorized MGE to increase 2015 rates for retail electric customers by 3.8 % or $ 15.4 million and to decrease gas rates by 2.0 % or $ 3.8 million. The increase in retail electric rates cover costs associated with the construction of emission-reduction equipment at Columbia, imp rovements and relia bility of the state's electric transmission system, fuel and purchased power related to coal delivery costs, partially offset by lower cost as a result of market conditions for pension and post retirement benefit costs. The authorized ret urn on common stock equity wa s 10.2 %. The PSCW also approved changes to customer rates and rate design for gas service that became effective January 1, 2015 . Gas rate design consists of a fixed monthly customer charge and a variable charge tied to actual usage, in addition to the separate charge through the PGA for natural gas commodity costs . The change shifted more of the rate recovery to the monthly charge, reflecting the related fixed costs of providing gas services, and reduced the variable usage-based charge. Thus, gas net income is expected to be more evenly distributed during the yea r and less sensitive to weather . b. Fuel R ules. 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 on an annual basis and is adjusted 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, les s 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 ret urn 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 th at order. In August 2015, the PSCW approved a $0.00256/kWh fuel credit that began on September 1, 2015, and will continue throughout 2016. The fuel credit established a mechanism to return $ 10.9 million of fuel savings to elect ric customers as a bill credit. MGE returned $ 2.6 million of electric fuel-related savings to customers through bill credits during the period from September 1, 2015, through December 31, 2015. MGE returned $ 6.3 million of electric fuel-related savings during the nine months ended September 30, 2016 . In January 2016, the PSCW lowered MGE ' s 2016 fuel rules monitored costs by $ 14.8 million as a result of continued lower projected fuel costs in 2016. Also, in March 2016, MGE filed its 2015 fuel plan reconciliation application showing an overcollection of 2015 fuel rules monitored costs. In July 2016, the PSCW issued a final order sta ting that MGE shall refund the additional fuel savings incurred during 2015 and 2016 for a total of $ 15.7 million to its retail electric customers over a one-month period. In September 2016, MGE returned $ 15.5 million to customers through bill credits. As of September 30, 2016 , MGE has deferred $ 4.1 million of 2016 fuel savings that were in excess of the fuel savings included within the fuel credits referenced above. These costs will be subject to the PSCW ' s annual review of 2016 fuel costs, expected to be completed in 2017 .

Fair Value of Financial Instrum

Fair Value of Financial Instruments	9 Months Ended
	Sep. 30, 2016
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 ass umptions 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 p rices 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 mod el-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. At September 30, 2016 , and December 31, 2015 , 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 MGE Energy's and MGE ' s long-term debt is based on quoted market prices for similar financial instruments at September 30, 2016 , and December 31, 2015 . Since long-term debt is not traded in an active market, it is classified as Level 2. The estimated fair market valu e s of financial instruments are as follows: September 30, 2016 December 31, 2015 (In thousands) Carrying Amount Fair Value Carrying Amount Fair Value MGE Energy Assets: Cash and cash equivalents $ 111,585 $ 111,585 $ 81,384 $ 81,384 Liabilities: Long-term debt (a) 392,316 463,849 395,508 435,767 MGE Assets: Cash and cash equivalents $ 31,558 $ 31,558 $ 26,760 $ 26,760 Liabilities: Long-term debt (a) 392,316 463,849 395,508 435,767 (a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.2 million and $4.5 million at September 30, 2016, and December 31, 2015, respectively. b. Recurring Fair Value Measurements. The following table presents the balances of assets and liabilities measured at fair value on a recurr ing basis . Fair Value as of September 30, 2016 (In thousands) Total Level 1 Level 2 Level 3 MGE Energy Assets: Derivatives $ 1,367 $ 917 $ - $ 450 Exchange-traded investments 520 520 - - Total Assets $ 1,887 $ 1,437 $ - $ 450 Liabilities: Derivatives $ 50,938 $ 59 $ - $ 50,879 Deferred compensation 2,963 - 2,963 - Total Liabilities $ 53,901 $ 59 $ 2,963 $ 50,879 MGE Assets: Derivatives $ 1,367 $ 917 $ - $ 450 Exchange-traded investments 97 97 - - Total Assets $ 1,464 $ 1,014 $ - $ 450 Liabilities: Derivatives $ 50,938 $ 59 $ - $ 50,879 Deferred compensation 2,963 - 2,963 - Total Liabilities $ 53,901 $ 59 $ 2,963 $ 50,879 Fair Value as of December 31, 2015 (In thousands) Total Level 1 Level 2 Level 3 MGE Energy Assets: Derivatives $ 234 $ - $ - $ 234 Exchange-traded investments 759 759 - - Total Assets $ 993 $ 759 $ - $ 234 Liabilities: Derivatives (b) $ 54,316 $ 581 $ - $ 53,735 Deferred compensation 3,145 - 3,145 - Total Liabilities $ 57,461 $ 581 $ 3,145 $ 53,735 MGE Assets: Derivatives $ 234 $ - $ - $ 234 Exchange-traded investments 148 148 - - Total Assets $ 382 $ 148 $ - $ 234 Liabilities: Derivatives (b) $ 54,316 $ 581 $ - $ 53,735 Deferred compensation 3,145 - 3,145 - Total Liabilities $ 57,461 $ 581 $ 3,145 $ 53,735 (b) These amounts are shown gross and exclude $1.0 million of collateral that was posted against derivative positions with counterparties as of December 31, 2015. No transfers were made in or out of Level 1 or Level 2 for the nine months ended September 30, 2016 . I nvestments include exchange-traded investment securities valued using quoted prices on active exchanges and are therefore classified as Level 1. Derivatives include exchange-traded derivative c ontracts, 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 class ified 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-cou nter 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 sim ilar instruments in a closed market with limited data available and are therefore classified as Level 3. The purchased power agreement (see Footnote 8 ) was valued using an internally-developed pricing model and therefore is classified as Level 3. The mod el 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 , where such exchange-traded contracts exist, and upon calculations based on forward gas prices, where such exchange-traded contracts do not exist. 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 fai r 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 cons iders 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 incor porates 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, 2016 December 31, 2015 Basis adjustment: On peak 93.3 % 96.9 % Off peak 94.1 % 95.1 % Counterparty fuel mix: Internal generation 55% - 75% 60% - 75% Purchased power 45% - 25% 40% - 25% 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 of MGE Energy and MGE. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26 w eek 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 mark et, they are classified as Level 2 . The following table summarizes the changes in Level 3 commodity derivative assets and liabilities measured at fair value on a recurring b asis . Three Months Ended Nine Months Ended September 30, September 30, (In thousands) 2016 2015 2016 2015 Beginning balance $ (51,883) $ (56,194) $ (53,501) $ (53,986) Realized and unrealized gains (losses): Included in regulatory liabilities (assets) 1,455 (888) 3,073 (3,096) Included in other comprehensive income - - - - Included in earnings (278) (2,285) (4,250) (4,497) Included in current assets - - - - Purchases 5,814 6,364 16,751 17,497 Sales - - - - Issuances - - - - Settlements (5,537) (4,079) (12,502) (13,000) Transfers in and/or out of Level 3 - - - - Balance as of September 30, $ (50,429) $ (57,082) $ (50,429) $ (57,082) 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) 2016 2015 2016 2015 Purchased Power Expense $ (278) $ (2,302) $ (4,250) $ (4,515) Cost of Gas Sold Expense - 17 - 18 Total $ (278) $ (2,285) $ (4,250) $ (4,497) (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.

New Accounting Pronouncements

New Accounting Pronouncements	9 Months Ended
	Sep. 30, 2016
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
New Accounting Pronouncements	New Accounting Pronouncements - MGE Energy and MGE. a. Revenue from Contracts with Customers . In May 2014, the FASB issued authoritative guidance within the Codification ' s Revenue Recognition topic that provides guidance on the recognition, measurement, and disclosure of revenue from contracts with customers. This authoritative guidance will become effective January 1, 2018. MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements. b. C onsolidation . In February 2015, the FASB issued authoritative guidance within the Codification ' s Consolidation topic that provides guidance on the evaluation of certain legal entities for consolidation purposes. This authoritative guidance became effectiv e January 1, 2016. This guidance had no impact on our financial statements. c. Debt Issuance Costs . In April 2015, the FASB issued authoritative guidance within the Codification's Interest topic that provides guidance on the presentation of debt issuance costs in financial statements. This authoritative guidance became effective January 1, 2016, and changed the presentation of debt issuance costs on the balance sheet. Prior to the authoritative guidance, debt issuance costs were treated a s a deferred asset, and beginning January 1, 2016, these costs are included as a direct deduction to the related debt liability on the consolidat ed balance sheet. As of September 30 , 2016 , assets (other deferred assets and other ) and liabilities (long-term de bt) decreased approximately $4.0 million as a cumulative result of the guidance. In addition, this guidance was applied retrospectively to all prior periods presented, resulting in a decrease t o assets and liabilities of $4.3 million for the year ended D ecember 31, 2015. d . Financial Instruments . In January 201 6 , the FASB issued authoritative guidance within the Codification's Financial Instruments topic that provides guidance on the recognition and measurement of financial instruments . This author itati ve guidance will become effective January 1, 201 8, and will require equity investments to be measured at fair value with changes in fair value recognized in net income rather than in other comprehensive income . The impact of this guidance on our financial statements is not expected to be material . e . Leases . In February 2016 , the FASB issued authoritative guidance within the Leases topic that provides guidance on the classification, recognition, measurement, and disclosure of leases . This authoritative gu idance will become effective January 1, 2019 . MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements .

Segment Information

Segment Information	9 Months Ended
	Sep. 30, 2016
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 MGE Energy ' s and MGE ' s 2015 Annual Report on Form 10-K for additional discussion of each of these segments. The following table s 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, 2016 Operating revenues $ 118,933 $ 17,570 $ 214 $ - $ - $ - $ 136,717 Interdepartmental revenues 459 6,040 10,998 - - (17,497) - Total operating revenues 119,392 23,610 11,212 - - (17,497) 136,717 Depreciation and amortization (7,332) (2,047) (1,833) - - - (11,212) Other operating expenses (77,010) (19,292) (33) (13) (127) 17,497 (78,978) Operating income (loss) 35,050 2,271 9,346 (13) (127) - 46,527 Other income (deductions), net 178 13 - 2,023 (109) - 2,105 Interest (expense) income, net (2,855) (818) (1,436) - 71 - (5,038) Income (loss) before taxes 32,373 1,466 7,910 2,010 (165) - 43,594 Income tax (provision) benefit (11,290) (494) (3,175) (812) 57 - (15,714) Net income (loss) $ 21,083 $ 972 $ 4,735 $ 1,198 $ (108) $ - $ 27,880 Three Months Ended September 30, 2015 Operating revenues $ 121,453 $ 17,431 $ 1,911 $ - $ - $ - $ 140,795 Interdepartmental revenues 163 3,855 9,866 - - (13,884) - Total operating revenues 121,616 21,286 11,777 - - (13,884) 140,795 Depreciation and amortization (7,584) (1,714) (1,872) - (12) - (11,182) Other operating expenses (80,202) (16,906) (36) (15) (161) 13,884 (83,436) Operating income (loss) 33,830 2,666 9,869 (15) (173) - 46,177 Other income (deductions), net 141 (7) - 2,397 33 - 2,564 Interest (expense) income, net (2,798) (804) (1,491) - 57 - (5,036) Income (loss) before taxes 31,173 1,855 8,378 2,382 (83) - 43,705 Income tax (provision) benefit (10,321) (732) (3,362) (962) 26 - (15,351) Net income (loss) $ 20,852 $ 1,123 $ 5,016 $ 1,420 $ (57) $ - $ 28,354 Nine Months Ended September 30, 2016 Operating revenues $ 312,470 $ 92,368 $ 982 $ - $ - $ - $ 405,820 Interdepartmental revenues 1,482 17,278 32,894 - - (51,654) - Total operating revenues 313,952 109,646 33,876 - - (51,654) 405,820 Depreciation and amortization (21,754) (6,043) (5,537) - (24) - (33,358) Other operating expenses (230,680) (88,328) (115) (17) (706) 51,654 (268,192) Operating income (loss) 61,518 15,275 28,224 (17) (730) - 104,270 Other income (deductions), net 492 (13) - 6,023 224 - 6,726 Interest (expense) income, net (8,421) (2,425) (4,348) - 199 - (14,995) Income (loss) before taxes 53,589 12,837 23,876 6,006 (307) - 96,001 Income tax (provision) benefit (17,984) (5,048) (9,583) (2,418) 90 - (34,943) Net income (loss) $ 35,605 $ 7,789 $ 14,293 $ 3,588 $ (217) $ - $ 61,058 Nine Months Ended September 30, 2015 Operating revenues $ 319,174 $ 108,028 $ 5,853 $ - $ - $ - $ 433,055 Interdepartmental revenues 400 8,871 29,566 - - (38,837) - Total operating revenues 319,574 116,899 35,419 - - (38,837) 433,055 Depreciation and amortization (22,372) (5,018) (5,601) - (35) - (33,026) Other operating expenses (239,963) (96,063) (122) (15) (626) 38,837 (297,952) Operating income (loss) 57,239 15,818 29,696 (15) (661) - 102,077 Other income (deductions), net 247 (33) - 6,568 333 - 7,115 Interest (expense) income, net (8,385) (2,398) (4,516) - 164 - (15,135) Income (loss) before taxes 49,101 13,387 25,180 6,553 (164) - 94,057 Income tax (provision) benefit (15,868) (5,370) (10,106) (2,637) 35 - (33,946) Net income (loss) $ 33,233 $ 8,017 $ 15,074 $ 3,916 $ (129) $ - $ 60,111 The following table s show segment information for MGE ' s operations for the indicated periods : (In thousands) MGE Electric Gas Non- Regulated Energy Transmission Investment (b) Consolidation/ Elimination Entries Consolidated Total Three Months Ended September 30, 2016 Operating revenues $ 118,938 $ 17,576 $ 214 $ - $ - $ 136,728 Interdepartmental revenues 454 6,034 10,998 - (17,486) - Total operating revenues 119,392 23,610 11,212 - (17,486) 136,728 Depreciation and amortization (7,332) (2,047) (1,833) - - (11,212) Other operating expenses (a) (88,282) (19,781) (3,208) 4 17,486 (93,781) Operating income (a) 23,778 1,782 6,171 4 - 31,735 Other income, net (a) 160 8 - 868 - 1,036 Interest expense, net (2,855) (818) (1,436) - - (5,109) Net income 21,083 972 4,735 872 - 27,662 Less: Net income attributable to noncontrolling interest, net of tax - - - - (5,695) (5,695) Net income attributable to MGE $ 21,083 $ 972 $ 4,735 $ 872 $ (5,695) $ 21,967 Three Months Ended September 30, 2015 Operating revenues $ 121,460 $ 17,435 $ 1,911 $ - $ - $ 140,806 Interdepartmental revenues 156 3,851 9,866 - (13,873) - Total operating revenues 121,616 21,286 11,777 - (13,873) 140,806 Depreciation and amortization (7,584) (1,714) (1,872) - - (11,170) Other operating expenses (a) (90,511) (17,635) (3,398) (15) 13,873 (97,686) Operating income (loss) (a) 23,521 1,937 6,507 (15) - 31,950 Other (deductions) income, net (a) 129 (10) - 1,435 - 1,554 Interest expense, net (2,798) (804) (1,491) - - (5,093) Net income 20,852 1,123 5,016 1,420 - 28,411 Less: Net income attributable to noncontrolling interest, net of tax - - - - (6,633) (6,633) Net income attributable to MGE $ 20,852 $ 1,123 $ 5,016 $ 1,420 $ (6,633) $ 21,778 Nine Months Ended September 30, 2016 Operating revenues $ 312,488 $ 92,390 $ 982 $ - $ - $ 405,860 Interdepartmental revenues 1,464 17,256 32,894 - (51,614) - Total operating revenues 313,952 109,646 33,876 - (51,614) 405,860 Depreciation and amortization (21,754) (6,043) (5,537) - - (33,334) Other operating expenses (a) (248,566) (93,348) (9,698) - 51,614 (299,998) Operating income (a) 43,632 10,255 18,641 - - 72,528 Other income (deductions), net (a) 394 (41) - 3,262 - 3,615 Interest expense, net (8,421) (2,425) (4,348) - - (15,194) Net income 35,605 7,789 14,293 3,262 - 60,949 Less: Net income attributable to noncontrolling interest, net of tax - - - - (17,899) (17,899) Net income attributable to MGE $ 35,605 $ 7,789 $ 14,293 $ 3,262 $ (17,899) $ 43,050 Nine Months Ended September 30, 2015 Operating revenues $ 319,191 $ 108,039 $ 5,853 $ - $ - $ 433,083 Interdepartmental revenues 383 8,860 29,566 - (38,809) - Total operating revenues 319,574 116,899 35,419 - (38,809) 433,083 Depreciation and amortization (22,372) (5,018) (5,601) - - (32,991) Other operating expenses (a) (255,732) (101,405) (10,228) (15) 38,809 (328,571) Operating income (loss) (a) 41,470 10,476 19,590 (15) - 71,521 Other income (deductions), net (a) 148 (61) - 3,931 - 4,018 Interest expense, net (8,385) (2,398) (4,516) - - (15,299) Net income 33,233 8,017 15,074 3,916 - 60,240 Less: Net income attributable to noncontrolling interest, net of tax - - - - (19,812) (19,812) Net income attributable to MGE $ 33,233 $ 8,017 $ 15,074 $ 3,916 $ (19,812) $ 40,428 (a) Amounts are shown net of the related tax expense, consistent with the presentation on the MGE Consolidated Statement of Income. (b) As of July 31, 2016, MGE no longer consolidates MGE Energy's proportionate share of equity earnings in MGE Transco. See Footnote 3 for further discussion.

Significant Accounting Policies

Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2016
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. B oth 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 .
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.
Investments - ATC	MGE Transco has accounted for its investment in ATC under the equity method of accounting.
Share-based Compensation	Under MGE Energy ' s Performance Unit Plan and the Director Incentive Plan, eligible employees and non-employee directors 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 set performance period. In Jan uary 2016 , 3,773 units were granted under the Director Incentive Plan and are subject to a three-year graded vesting schedule . In February 2016 , 19,055 units were gr anted under the Performance Unit Plan and are subject to a five-year graded vesting schedule. On the grant d ate, MGE Energy and MGE measure the cost of the employee services received in exchange for a performance unit award based on the current market valu e of MGE Energy common stock. The fair value of the awards is re-measured quarterly, including at September 30, 2016 , as required by applicable accounting standards. Changes in fair value as well as the original grant are recognized as compensation cost. Si nce this amount is re-measured 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 grade d 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.
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, MGE Energy and MGE recognize such derivatives in the co nsolidated 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 st rategies. 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 regulato ry asset or liability. 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 electri c 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 collatera l. For financia l statement purposes, MGE Energy and MGE have netted instruments with the same counterparty under a master netting agreement as well as the netting of collatera l.
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 on an annual basis and is adjusted 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, les s 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 ret urn 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 th at order.
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 ass umptions 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 p rices 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 mod el-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. At September 30, 2016 , and December 31, 2015 , 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 MGE Energy's and MGE ' s long-term debt is based on quoted market prices for similar financial instruments at September 30, 2016 , and December 31, 2015 . Since long-term debt is not traded in an active market, it is classified as Level 2. I nvestments include exchange-traded investment securities valued using quoted prices on active exchanges and are therefore classified as Level 1. Derivatives include exchange-traded derivative c ontracts, 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 class ified 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-cou nter 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 sim ilar instruments in a closed market with limited data available and are therefore classified as Level 3. The purchased power agreement (see Footnote 8 ) was valued using an internally-developed pricing model and therefore is classified as Level 3. The mod el 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 , where such exchange-traded contracts exist, and upon calculations based on forward gas prices, where such exchange-traded contracts do not exist. 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 fai r 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 cons iders 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 incor porates 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, 2016 December 31, 2015 Basis adjustment: On peak 93.3 % 96.9 % Off peak 94.1 % 95.1 % Counterparty fuel mix: Internal generation 55% - 75% 60% - 75% Purchased power 45% - 25% 40% - 25% 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 of MGE Energy and MGE. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26 w eek 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 mark et, they are classified as Level 2 .
New Accounting Pronouncements Disclosure	New Accounting Pronouncements - MGE Energy and MGE. a. Revenue from Contracts with Customers . In May 2014, the FASB issued authoritative guidance within the Codification ' s Revenue Recognition topic that provides guidance on the recognition, measurement, and disclosure of revenue from contracts with customers. This authoritative guidance will become effective January 1, 2018. MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements. b. C onsolidation . In February 2015, the FASB issued authoritative guidance within the Codification ' s Consolidation topic that provides guidance on the evaluation of certain legal entities for consolidation purposes. This authoritative guidance became effectiv e January 1, 2016. This guidance had no impact on our financial statements. c. Debt Issuance Costs . In April 2015, the FASB issued authoritative guidance within the Codification's Interest topic that provides guidance on the presentation of debt issuance costs in financial statements. This authoritative guidance became effective January 1, 2016, and changed the presentation of debt issuance costs on the balance sheet. Prior to the authoritative guidance, debt issuance costs were treated a s a deferred asset, and beginning January 1, 2016, these costs are included as a direct deduction to the related debt liability on the consolidat ed balance sheet. As of September 30 , 2016 , assets (other deferred assets and other ) and liabilities (long-term de bt) decreased approximately $4.0 million as a cumulative result of the guidance. In addition, this guidance was applied retrospectively to all prior periods presented, resulting in a decrease t o assets and liabilities of $4.3 million for the year ended D ecember 31, 2015. d . Financial Instruments . In January 201 6 , the FASB issued authoritative guidance within the Codification's Financial Instruments topic that provides guidance on the recognition and measurement of financial instruments . This author itati ve guidance will become effective January 1, 201 8, and will require equity investments to be measured at fair value with changes in fair value recognized in net income rather than in other comprehensive income . The impact of this guidance on our financial statements is not expected to be material . e . Leases . In February 2016 , the FASB issued authoritative guidance within the Leases topic that provides guidance on the classification, recognition, measurement, and disclosure of leases . This authoritative gu idance will become effective January 1, 2019 . MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements .

Investment in ATC (Tables)

Investment in ATC (Tables)	9 Months Ended
	Sep. 30, 2016
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments Financial Data	For the three and nine months ended September 30, 2016 and 2015 , MGE Transco recorded the following : Three Months Ended Nine Months Ended September 30, September 30, (In thousands) 2016 2015 2016 2015 Equity earnings from investment in ATC $ 2,023 $ 2,398 $ 6,023 $ 6,568 Dividends received from ATC 1,486 1,841 4,214 4,732 Capital contributions to ATC 888 177 1,598 533 For the three and nine months ended September 30, 2016 and 2015 , MGE recorded the following amounts attributable to noncontrolling interest in MGE Transco: Three Months Ended Nine Months Ended September 30, September 30, (In thousands) 2016 2015 2016 2015 Equity earnings from investment (a) $ 254 $ 679 $ 1,410 $ 1,848 Dividends received from investment (a) 561 423 1,113 1,007 Capital contributions by noncontrolling interest 888 177 1,598 533 (a ) Amounts reflected net of tax. ATC ' s summarized financial data for the three and nine months ended September 30, 2016 an d 2015 , is as follows: Three Months Ended Nine Months Ended September 30, September 30, (In thousands) 2016 2015 2016 2015 Operating revenues $ 158,126 $ 164,515 $ 476,591 $ 482,043 Operating expenses (80,271) (78,059) (241,034) (238,336) Other income, net 1,128 585 2,563 566 Interest expense, net (24,624) (23,655) (73,714) (72,310) Earnings before members' income taxes $ 54,359 $ 63,386 $ 164,406 $ 171,963

Pension and Other Postretirem28

Pension and Other Postretirement Plans (Tables)	9 Months Ended
	Sep. 30, 2016
Compensation and Retirement Disclosure [Abstract]
Schedule of Net Periodic Benefit Costs	The following table presents the components of MGE Energy's and MGE's net periodic benefit costs recognized for the three and nine months ended September 30, 2016 and 2015 . A portion of the net periodic benefit cost is capitalized within the consolidated b alance sheets. Three Months Ended Nine Months Ended September 30, September 30, (In thousands) 2016 2015 2016 2015 Pension Benefits Components of net periodic cost: Service cost $ 1,413 $ 1,878 $ 4,358 $ 5,715 Interest cost 3,161 3,594 9,744 10,936 Expected return on assets (5,724) (5,930) (17,646) (18,045) Amortization of: Prior service cost 3 6 8 18 Actuarial loss 1,388 1,393 4,278 4,240 Net periodic cost $ 241 $ 941 $ 742 $ 2,864 Postretirement Benefits Components of net periodic (benefit) cost: Service cost $ 361 $ 194 $ 1,084 $ 580 Interest cost 753 392 2,258 1,176 Expected return on assets (787) (355) (2,360) (1,063) Amortization of: Transition obligation 1 - 3 1 Prior service benefit (744) (337) (2,233) (1,009) Actuarial loss 178 133 533 397 Net periodic (benefit) cost $ (238) $ 27 $ (715) $ 82

Commitments and Contingencies (

Commitments and Contingencies (Tables)	9 Months Ended
	Sep. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Purchase Contracts, Fiscal Year Maturity Schedule	As of September 30, 2016 , the future commitments related to these purchase contracts were as follows: (In thousands) 2016 2017 2018 2019 2020 Thereafter Coal (a) $ 23,260 $ 16,535 $ 12,640 $ 3,850 $ - $ - Natural gas Transportation & storage (b) 6,005 20,858 20,644 19,482 15,225 31,767 Supply (c) 11,661 12,580 - - - - $ 40,926 $ 49,973 $ 33,284 $ 23,332 $ 15,225 $ 31,767 (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. If any minimum purchase obligations must be paid under these contracts, management believes these obligations would be considered costs of service and recoverable in rates. (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. Management expects to recover these costs in future customer rates . (c) These commitments include market-based pricing. Management expects to recover these costs in future customer rates .

Derivative and Hedging Instru30

Derivative and Hedging Instruments (Tables)	9 Months Ended
	Sep. 30, 2016
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, 2016 December 31, 2015 Commodity derivative contracts 465,835 MWh 355,580 MWh Commodity derivative contracts 6,157,500 Dth 5,037,500 Dth FTRs 3,567 MW 2,000 MW
Fair Value of Derivative Instruments on the Balance Sheet	The following table summarizes the fair value of the derivative instruments on the consolidat ed balance sheet s . 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 collatera l. For financia l statement purposes, MGE Energy and MGE have netted instruments with the same counterparty under a master netting agreement as well as the netting of collatera l. As of September 30, 2016 and December 31, 2015 , MGE Energy and MGE had a receivable – marg in account balance of $ 1.6 million and $ 2.3 million, respectively, which is shown net of any collateral posted against derivative positions . Asset Derivatives Liability Derivatives (In thousands) Balance Sheet Location Fair Value Balance Sheet Location Fair Value September 30, 2016 Commodity derivative contracts Other current assets $ 1,023 Derivative liability (current) $ 351 Commodity derivative contracts Other deferred charges 114 Derivative liability (long-term) 97 FTRs Other current assets 230 Derivative liability (current) - PPA N/A N/A Derivative liability (current) 8,030 PPA N/A N/A Derivative liability (long-term) 42,460 December 31, 2015 Commodity derivative contracts Other current assets $ 146 Derivative liability (current) $ 1,266 Commodity derivative contracts Other deferred charges 144 Derivative liability (long-term) 70 FTRs Other current assets 234 Derivative liability (current) - PPA N/A N/A Derivative liability (current) 8,340 PPA N/A N/A Derivative liability (long-term) 44,930
Offsetting Assets	The foll owing tables show the ef fect of netting arrangements for recognized derivative assets and liabilities that are subject to a master netting arr angement 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, 2016 Commodity derivative contracts $ 1,137 $ (448) $ - $ 689 FTRs 230 - - 230 December 31, 2015 Commodity derivative contracts $ 290 $ (290) $ - $ - FTRs 234 - - 234
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, 2016 Commodity derivative contracts $ 448 $ (448) $ - $ - PPA 50,490 - - 50,490 December 31, 2015 Commodity derivative contracts $ 1,336 $ (290) $ (1,038) $ 8 PPA 53,270 - - 53,270
Derivative Gains and Losses in Balance Sheet	The following table s summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheet s at September 30, 2016 and 2015 , and the consolidated income statement s for the three and nine months ended September 30, 2016 and 2015 . 2016 2015 (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, $ 50,521 $ 659 $ 56,048 $ 455 Unrealized (gain) loss (663) - 4,036 - Realized gain (loss) reclassified to a deferred account 17 (17) (408) 408 Realized (loss) gain reclassified to income statement (304) 46 (2,278) (91) Balance at September 30, $ 49,571 $ 688 $ 57,398 $ 772 Nine Months Ended September 30: Balance at January 1, $ 54,082 $ 1,208 $ 54,998 $ 1,001 Unrealized loss 1,128 - 8,514 - Realized (loss) gain reclassified to a deferred account (1,417) 1,417 (1,700) 1,700 Realized (loss) gain reclassified to income statement (4,222) (1,937) (4,414) (1,929) Balance at September 30, $ 49,571 $ 688 $ 57,398 $ 772
Derivative Gains and Losses in Income Statement	Realized Losses (Gains) 2016 2015 (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 $ 45 $ - $ 862 $ (17) FTRs (703) - (233) - PPA 916 - 1,757 - Nine Months Ended September 30: Commodity derivative contracts $ 1,469 $ 1,814 $ 1,860 $ 1,742 FTRs (635) - (607) - PPA 3,511 - 3,348 -

Fair Value of Financial Instr31

Fair Value of Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 2016
Fair Value Disclosures [Abstract]
Estimated Fair Market Value of Financial Instruments	The estimated fair market valu e s of financial instruments are as follows: September 30, 2016 December 31, 2015 (In thousands) Carrying Amount Fair Value Carrying Amount Fair Value MGE Energy Assets: Cash and cash equivalents $ 111,585 $ 111,585 $ 81,384 $ 81,384 Liabilities: Long-term debt (a) 392,316 463,849 395,508 435,767 MGE Assets: Cash and cash equivalents $ 31,558 $ 31,558 $ 26,760 $ 26,760 Liabilities: Long-term debt (a) 392,316 463,849 395,508 435,767 (a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.2 million and $4.5 million at September 30, 2016, and December 31, 2015, 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 recurr ing basis . Fair Value as of September 30, 2016 (In thousands) Total Level 1 Level 2 Level 3 MGE Energy Assets: Derivatives $ 1,367 $ 917 $ - $ 450 Exchange-traded investments 520 520 - - Total Assets $ 1,887 $ 1,437 $ - $ 450 Liabilities: Derivatives $ 50,938 $ 59 $ - $ 50,879 Deferred compensation 2,963 - 2,963 - Total Liabilities $ 53,901 $ 59 $ 2,963 $ 50,879 MGE Assets: Derivatives $ 1,367 $ 917 $ - $ 450 Exchange-traded investments 97 97 - - Total Assets $ 1,464 $ 1,014 $ - $ 450 Liabilities: Derivatives $ 50,938 $ 59 $ - $ 50,879 Deferred compensation 2,963 - 2,963 - Total Liabilities $ 53,901 $ 59 $ 2,963 $ 50,879 Fair Value as of December 31, 2015 (In thousands) Total Level 1 Level 2 Level 3 MGE Energy Assets: Derivatives $ 234 $ - $ - $ 234 Exchange-traded investments 759 759 - - Total Assets $ 993 $ 759 $ - $ 234 Liabilities: Derivatives (b) $ 54,316 $ 581 $ - $ 53,735 Deferred compensation 3,145 - 3,145 - Total Liabilities $ 57,461 $ 581 $ 3,145 $ 53,735 MGE Assets: Derivatives $ 234 $ - $ - $ 234 Exchange-traded investments 148 148 - - Total Assets $ 382 $ 148 $ - $ 234 Liabilities: Derivatives (b) $ 54,316 $ 581 $ - $ 53,735 Deferred compensation 3,145 - 3,145 - Total Liabilities $ 57,461 $ 581 $ 3,145 $ 53,735 (b) These amounts are shown gross and exclude $1.0 million of collateral that was posted against derivative positions with counterparties as of December 31, 2015.
Significant Unobservable Inputs	The following table presents the significant unobservable inputs used in the pricing model. Model Input Significant Unobservable Inputs September 30, 2016 December 31, 2015 Basis adjustment: On peak 93.3 % 96.9 % Off peak 94.1 % 95.1 % Counterparty fuel mix: Internal generation 55% - 75% 60% - 75% Purchased power 45% - 25% 40% - 25%
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 b asis . Three Months Ended Nine Months Ended September 30, September 30, (In thousands) 2016 2015 2016 2015 Beginning balance $ (51,883) $ (56,194) $ (53,501) $ (53,986) Realized and unrealized gains (losses): Included in regulatory liabilities (assets) 1,455 (888) 3,073 (3,096) Included in other comprehensive income - - - - Included in earnings (278) (2,285) (4,250) (4,497) Included in current assets - - - - Purchases 5,814 6,364 16,751 17,497 Sales - - - - Issuances - - - - Settlements (5,537) (4,079) (12,502) (13,000) Transfers in and/or out of Level 3 - - - - Balance as of September 30, $ (50,429) $ (57,082) $ (50,429) $ (57,082) 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) 2016 2015 2016 2015 Purchased Power Expense $ (278) $ (2,302) $ (4,250) $ (4,515) Cost of Gas Sold Expense - 17 - 18 Total $ (278) $ (2,285) $ (4,250) $ (4,497) (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.

Segment Information (Tables)

Segment Information (Tables)	9 Months Ended
	Sep. 30, 2016
Segment Reporting [Abstract]
Segment Information	The following table s 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, 2016 Operating revenues $ 118,933 $ 17,570 $ 214 $ - $ - $ - $ 136,717 Interdepartmental revenues 459 6,040 10,998 - - (17,497) - Total operating revenues 119,392 23,610 11,212 - - (17,497) 136,717 Depreciation and amortization (7,332) (2,047) (1,833) - - - (11,212) Other operating expenses (77,010) (19,292) (33) (13) (127) 17,497 (78,978) Operating income (loss) 35,050 2,271 9,346 (13) (127) - 46,527 Other income (deductions), net 178 13 - 2,023 (109) - 2,105 Interest (expense) income, net (2,855) (818) (1,436) - 71 - (5,038) Income (loss) before taxes 32,373 1,466 7,910 2,010 (165) - 43,594 Income tax (provision) benefit (11,290) (494) (3,175) (812) 57 - (15,714) Net income (loss) $ 21,083 $ 972 $ 4,735 $ 1,198 $ (108) $ - $ 27,880 Three Months Ended September 30, 2015 Operating revenues $ 121,453 $ 17,431 $ 1,911 $ - $ - $ - $ 140,795 Interdepartmental revenues 163 3,855 9,866 - - (13,884) - Total operating revenues 121,616 21,286 11,777 - - (13,884) 140,795 Depreciation and amortization (7,584) (1,714) (1,872) - (12) - (11,182) Other operating expenses (80,202) (16,906) (36) (15) (161) 13,884 (83,436) Operating income (loss) 33,830 2,666 9,869 (15) (173) - 46,177 Other income (deductions), net 141 (7) - 2,397 33 - 2,564 Interest (expense) income, net (2,798) (804) (1,491) - 57 - (5,036) Income (loss) before taxes 31,173 1,855 8,378 2,382 (83) - 43,705 Income tax (provision) benefit (10,321) (732) (3,362) (962) 26 - (15,351) Net income (loss) $ 20,852 $ 1,123 $ 5,016 $ 1,420 $ (57) $ - $ 28,354 Nine Months Ended September 30, 2016 Operating revenues $ 312,470 $ 92,368 $ 982 $ - $ - $ - $ 405,820 Interdepartmental revenues 1,482 17,278 32,894 - - (51,654) - Total operating revenues 313,952 109,646 33,876 - - (51,654) 405,820 Depreciation and amortization (21,754) (6,043) (5,537) - (24) - (33,358) Other operating expenses (230,680) (88,328) (115) (17) (706) 51,654 (268,192) Operating income (loss) 61,518 15,275 28,224 (17) (730) - 104,270 Other income (deductions), net 492 (13) - 6,023 224 - 6,726 Interest (expense) income, net (8,421) (2,425) (4,348) - 199 - (14,995) Income (loss) before taxes 53,589 12,837 23,876 6,006 (307) - 96,001 Income tax (provision) benefit (17,984) (5,048) (9,583) (2,418) 90 - (34,943) Net income (loss) $ 35,605 $ 7,789 $ 14,293 $ 3,588 $ (217) $ - $ 61,058 Nine Months Ended September 30, 2015 Operating revenues $ 319,174 $ 108,028 $ 5,853 $ - $ - $ - $ 433,055 Interdepartmental revenues 400 8,871 29,566 - - (38,837) - Total operating revenues 319,574 116,899 35,419 - - (38,837) 433,055 Depreciation and amortization (22,372) (5,018) (5,601) - (35) - (33,026) Other operating expenses (239,963) (96,063) (122) (15) (626) 38,837 (297,952) Operating income (loss) 57,239 15,818 29,696 (15) (661) - 102,077 Other income (deductions), net 247 (33) - 6,568 333 - 7,115 Interest (expense) income, net (8,385) (2,398) (4,516) - 164 - (15,135) Income (loss) before taxes 49,101 13,387 25,180 6,553 (164) - 94,057 Income tax (provision) benefit (15,868) (5,370) (10,106) (2,637) 35 - (33,946) Net income (loss) $ 33,233 $ 8,017 $ 15,074 $ 3,916 $ (129) $ - $ 60,111 The following table s show segment information for MGE ' s operations for the indicated periods : (In thousands) MGE Electric Gas Non- Regulated Energy Transmission Investment (b) Consolidation/ Elimination Entries Consolidated Total Three Months Ended September 30, 2016 Operating revenues $ 118,938 $ 17,576 $ 214 $ - $ - $ 136,728 Interdepartmental revenues 454 6,034 10,998 - (17,486) - Total operating revenues 119,392 23,610 11,212 - (17,486) 136,728 Depreciation and amortization (7,332) (2,047) (1,833) - - (11,212) Other operating expenses (a) (88,282) (19,781) (3,208) 4 17,486 (93,781) Operating income (a) 23,778 1,782 6,171 4 - 31,735 Other income, net (a) 160 8 - 868 - 1,036 Interest expense, net (2,855) (818) (1,436) - - (5,109) Net income 21,083 972 4,735 872 - 27,662 Less: Net income attributable to noncontrolling interest, net of tax - - - - (5,695) (5,695) Net income attributable to MGE $ 21,083 $ 972 $ 4,735 $ 872 $ (5,695) $ 21,967 Three Months Ended September 30, 2015 Operating revenues $ 121,460 $ 17,435 $ 1,911 $ - $ - $ 140,806 Interdepartmental revenues 156 3,851 9,866 - (13,873) - Total operating revenues 121,616 21,286 11,777 - (13,873) 140,806 Depreciation and amortization (7,584) (1,714) (1,872) - - (11,170) Other operating expenses (a) (90,511) (17,635) (3,398) (15) 13,873 (97,686) Operating income (loss) (a) 23,521 1,937 6,507 (15) - 31,950 Other (deductions) income, net (a) 129 (10) - 1,435 - 1,554 Interest expense, net (2,798) (804) (1,491) - - (5,093) Net income 20,852 1,123 5,016 1,420 - 28,411 Less: Net income attributable to noncontrolling interest, net of tax - - - - (6,633) (6,633) Net income attributable to MGE $ 20,852 $ 1,123 $ 5,016 $ 1,420 $ (6,633) $ 21,778 Nine Months Ended September 30, 2016 Operating revenues $ 312,488 $ 92,390 $ 982 $ - $ - $ 405,860 Interdepartmental revenues 1,464 17,256 32,894 - (51,614) - Total operating revenues 313,952 109,646 33,876 - (51,614) 405,860 Depreciation and amortization (21,754) (6,043) (5,537) - - (33,334) Other operating expenses (a) (248,566) (93,348) (9,698) - 51,614 (299,998) Operating income (a) 43,632 10,255 18,641 - - 72,528 Other income (deductions), net (a) 394 (41) - 3,262 - 3,615 Interest expense, net (8,421) (2,425) (4,348) - - (15,194) Net income 35,605 7,789 14,293 3,262 - 60,949 Less: Net income attributable to noncontrolling interest, net of tax - - - - (17,899) (17,899) Net income attributable to MGE $ 35,605 $ 7,789 $ 14,293 $ 3,262 $ (17,899) $ 43,050 Nine Months Ended September 30, 2015 Operating revenues $ 319,191 $ 108,039 $ 5,853 $ - $ - $ 433,083 Interdepartmental revenues 383 8,860 29,566 - (38,809) - Total operating revenues 319,574 116,899 35,419 - (38,809) 433,083 Depreciation and amortization (22,372) (5,018) (5,601) - - (32,991) Other operating expenses (a) (255,732) (101,405) (10,228) (15) 38,809 (328,571) Operating income (loss) (a) 41,470 10,476 19,590 (15) - 71,521 Other income (deductions), net (a) 148 (61) - 3,931 - 4,018 Interest expense, net (8,385) (2,398) (4,516) - - (15,299) Net income 33,233 8,017 15,074 3,916 - 60,240 Less: Net income attributable to noncontrolling interest, net of tax - - - - (19,812) (19,812) Net income attributable to MGE $ 33,233 $ 8,017 $ 15,074 $ 3,916 $ (19,812) $ 40,428 (a) Amounts are shown net of the related tax expense, consistent with the presentation on the MGE Consolidated Statement of Income. (b) As of July 31, 2016, MGE no longer consolidates MGE Energy's proportionate share of equity earnings in MGE Transco. See Footnote 3 for further discussion.

Equity and Financing Arrangem33

Equity and Financing Arrangements (Details) - USD ($)	1 Months Ended	9 Months Ended
	Oct. 31, 2016	Sep. 30, 2016	Sep. 30, 2015
Common Stock [Abstract]
Common stock issued during period		0	0
Dilutive Shares Calculation [Abstract]
Dilutive securities		$ 0
Medium-Term Notes, 5.26% due 2017
Debt Instrument [Line Items]
Long-term debt, gross		$ 30,000,000
Future Debt Issuance, 3.76% due 2052 | Subsequent Event [Member]
Debt Instrument [Line Items]
Face amount	$ 40,000,000
Interest rate	3.76%
Term	35 years

Investment in ATC (Details-1)

Investment in ATC (Details-1) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment	$ 2,023	$ 2,398	$ 6,023	$ 6,568
Dividends received from investment	1,486	1,841	4,214	4,732
Capital contributions to investments	888	177	2,036	785
MGE Transco [Member] | ATC [Member]
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment	2,023	2,398	6,023	6,568
Dividends received from investment	1,486	1,841	4,214	4,732
Capital contributions to investments	888	177	1,598	533
Equity method investment	72,900		72,900		$ 69,500
MGE [Member]
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment	1,451	2,398	5,451	6,568
Dividends received from investment	1,486	1,841	4,214	4,732
Capital contributions to investments	888	$ 177	1,598	$ 533
MGE [Member] | MGE Transco [Member]
Schedule Of Equity Method Investments [Line Items]
Equity method investment	$ 46,800		$ 46,800

Investment in ATC (Details-2)

Investment in ATC (Details-2) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Minority Interest [Line Items]
Equity earnings from investment		$ 2,023	$ 2,398	$ 6,023	$ 6,568
Dividends received from investment		1,486	1,841	4,214	4,732
Capital contributions to investments		$ 888	177	$ 2,036	785
MGE Energy [Member]
Minority Interest [Line Items]
MGE Energy's ownership interest in MGE Transco		50.50%		50.50%
MGE [Member]
Minority Interest [Line Items]
Equity earnings from investment		$ 1,451	2,398	$ 5,451	6,568
Dividends received from investment		1,486	1,841	4,214	4,732
Capital contributions to investments		$ 888	177	$ 1,598	533
MGE's ownership interest in MGE Transco		49.50%		49.50%
Noncontrolling interest on balance sheet		$ 116,206		$ 116,206		$ 140,308
MGE [Member] | Noncontrolling Interest [Member] | MGE Transco [Member]
Minority Interest [Line Items]
Equity earnings from investment	[1]	254	679	1,410	1,848
Dividends received from investment	[1]	561	423	1,113	1,007
Capital contributions to investments		$ 888	$ 177	$ 1,598	$ 533
Noncontrolling interest on balance sheet						$ 23,600
[1]	Amounts reflected net of tax.

Investment in ATC (Details-3)

Investment in ATC (Details-3) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
ATC [Member]
Schedule Of Equity Method Investments [Line Items]
Operating revenues	$ 158,126	$ 164,515	$ 476,591	$ 482,043
Operating expenses	(80,271)	(78,059)	(241,034)	(238,336)
Other income, net	1,128	585	2,563	566
Interest expense, net	(24,624)	(23,655)	(73,714)	(72,310)
Earnings before members' income taxes	54,359	63,386	164,406	171,963
ATC [Member]
Related Party Transaction [Line Items]
Related party expenses	7,400	$ 7,000	22,100	$ 21,100
Due from related parties	$ 300		$ 300		$ 200

Taxes (Details)

Taxes (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Income Tax Disclosure [Line Items]
Effective income tax rate	36.10%	35.10%	36.40%	36.10%
MGE [Member]
Income Tax Disclosure [Line Items]
Effective income tax rate	36.00%	35.10%	36.40%	36.10%

Pension and Other Postretirem38

Pension and Other Postretirement Plans (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Pension Benefits [Member]
Components of net periodic cost (benefit):
Service cost	$ 1,413	$ 1,878	$ 4,358	$ 5,715
Interest cost	3,161	3,594	9,744	10,936
Expected return on assets	(5,724)	(5,930)	(17,646)	(18,045)
Amortization of:
Prior service cost (benefit)	3	6	8	18
Actuarial loss	1,388	1,393	4,278	4,240
Net periodic cost (benefit)	241	941	742	2,864
Postretirement Benefits [Member]
Components of net periodic cost (benefit):
Service cost	361	194	1,084	580
Interest cost	753	392	2,258	1,176
Expected return on assets	(787)	(355)	(2,360)	(1,063)
Amortization of:
Transition obligation	1	0	3	1
Prior service cost (benefit)	(744)	(337)	(2,233)	(1,009)
Actuarial loss	178	133	533	397
Net periodic cost (benefit)	$ (238)	$ 27	$ (715)	$ 82

Share Based Compensation (Detai

Share Based Compensation (Details) - Performance Units [Member] - USD ($) $ in Millions	Feb. 19, 2016	Jan. 31, 2016	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense			$ 0.2	$ 0.3	$ 2	$ 0.4
Cash payments distributed related to awards previously granted and now payable		$ 1.2
Awards forfeited during period, value					$ 0	$ 0.2
Awards forfeited during period, units					0	4,676
Outstanding awards vested during period					$ 5.8
Performance Unit Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)	19,055
Award vesting period					5 years
Director Incentive Agreement [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)		3,773
Award vesting period					3 years

Commitments and Contingencies40

Commitments and Contingencies (Details-1) - EPA [Member]	9 Months Ended
	Sep. 30, 2016ppbpollutantstateMW
Effluent Limitations Guidelines and Standards for Steam Electric Power Generating Source Category [Abstract]
Air pollution control and ash handling systems capacity at coal burning power plants, minimum (in MW) | MW	50
EPA's National Ambient Air Quality Standards
Number of pollutants monitored by the National Ambient Air Quality Standards | pollutant	6
Ozone NAAQS
Current primary regulated level of Ozone NAAQS (in parts per billion)	70
Current secondary regulated level of Ozone NAAQS (in parts per billion)	70
EPA's Cross State Air Pollution Rule
Number of states incorporating 2008 ozone NAAQS attainment levels | state	22

Commitments and Contingencies41

Commitments and Contingencies (Details-2) $ in Thousands	Sep. 30, 2016USD ($)
Operating expense purchase contracts [Abstract]
Purchase obligation, 2016	$ 40,926
Purchase obligation, 2017	49,973
Purchase obligation, 2018	33,284
Purchase obligation, 2019	23,332
Purchase obligation, 2020	15,225
Purchase obligation, Thereafter	31,767
Coal [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2016	23,260	[1]
Purchase obligation, 2017	16,535	[1]
Purchase obligation, 2018	12,640	[1]
Purchase obligation, 2019	3,850	[1]
Purchase obligation, 2020	0	[1]
Purchase obligation, Thereafter	0	[1]
Natural Gas, Transportation and Storage [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2016	6,005	[2]
Purchase obligation, 2017	20,858	[2]
Purchase obligation, 2018	20,644	[2]
Purchase obligation, 2019	19,482	[2]
Purchase obligation, 2020	15,225	[2]
Purchase obligation, Thereafter	31,767	[2]
Natual Gas, Supply [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2016	11,661	[3]
Purchase obligation, 2017	12,580	[3]
Purchase obligation, 2018	0	[3]
Purchase obligation, 2019	0	[3]
Purchase obligation, 2020	0	[3]
Purchase obligation, Thereafter	$ 0	[3]
[1]	Total coal commitments for the Columbia and Elm Road Units, including transportation. Fuel procurement for MGE's jointly owned Columbia and Elm Road Units is handled by WPL and WEPCO, respectively, who are the operators of those facilities. If any minimum purchase obligations must be paid under these contracts, management believes these obligations would be considered costs of service and recoverable in rates.
[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. Management expects to recover these costs in future customer rates .
[3]	These commitments include market-based pricing. Management expects to recover these costs in future customer rates .

Derivative and Hedging Instru42

Derivative and Hedging Instruments (Details-1) $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2016USD ($)DthMWhMW	Dec. 31, 2015USD ($)DthMWhMW	Jun. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Dec. 31, 2014USD ($)
Gross Notional Volume of Open Derivatives
Derivative, right to reclaim collateral (receivable)	$ 0
Receivable, margin account balance, net of collateral posted against derivative positions	1,600	$ 2,300
Other Current Assets [Member]
Derivative fair values [Abstract]
Derivative fair value, net	688	1,208	$ 659	$ 772	$ 455	$ 1,001
Commodity Contracts And Financial Transimission Rights [Member]
Derivative fair values [Abstract]
Derivative fair value, net	$ 900	$ (800)
Commodity Derivative Contracts [Member]
Gross Notional Volume of Open Derivatives
Notional amount, energy measure (in MWh) | MWh	465,835	355,580
Notional amount, decatherm measure (in Dth) | Dth	6,157,500	5,037,500
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	$ 1,137	$ 290
Liability Derivatives, fair value, gross basis	448	1,336
Commodity Derivative Contracts [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	1,023	146
Commodity Derivative Contracts [Member] | Other Deferred Charges [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	114	144
Commodity Derivative Contracts [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis	351	1,266
Commodity Derivative Contracts [Member] | Derivative Liability (Long-term) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis	$ 97	$ 70
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	3,567	2,000
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	$ 230	$ 234
Financial Transmission Rights [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	230	234
Financial Transmission Rights [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis	0	0
PPA [Member]
Derivative fair values [Abstract]
Derivative fair value, net	(50,500)	(53,300)
Liability Derivatives, fair value, gross basis	50,490	53,270
PPA [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis	8,030	8,340
PPA [Member] | Derivative Liability (Long-term) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis	$ 42,460	$ 44,930

Derivative and Hedging Instru43

Derivative and Hedging Instruments (Details-2) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Commodity Derivative Contracts [Member]
Offsetting Assets [Line Items]
Gross amounts	$ 1,137	$ 290
Gross amounts offset in balance sheet	(448)	(290)
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	689	0
Financial Transmission Rights [Member]
Offsetting Assets [Line Items]
Gross amounts	230	234
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 230	$ 234

Derivative and Hedging Instru44

Derivative and Hedging Instruments (Details-3) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Offsetting Liabilities [Line Items]
Collateral posted against derivative positions		$ (1,000)
Commodity Derivative Contracts [Member]
Offsetting Liabilities [Line Items]
Gross amounts	$ 448	1,336
Gross amounts offset in balance sheet	(448)	(290)
Collateral posted against derivative positions	0	(1,038)
Net amount presented in balance sheet	0	8
Purchased Power Agreement [Member]
Offsetting Liabilities [Line Items]
Gross amounts	50,490	53,270
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 50,490	$ 53,270

Derivative and Hedging Instru45

Derivative and Hedging Instruments (Details-4) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Current and Long-Term Regulatory Asset [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	$ 50,521	$ 56,048	$ 54,082	$ 54,998
Unrealized (gain) loss	(663)	4,036	1,128	8,514
Realized gain (loss) reclassified to a deferred account	17	(408)	(1,417)	(1,700)
Realized (loss) gain reclassified to income statement	(304)	(2,278)	(4,222)	(4,414)
Ending balance,	49,571	57,398	49,571	57,398
Other Current Assets [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	659	455	1,208	1,001
Unrealized (gain) loss	0	0	0	0
Realized gain (loss) reclassified to a deferred account	(17)	408	1,417	1,700
Realized (loss) gain reclassified to income statement	46	(91)	(1,937)	(1,929)
Ending balance,	$ 688	$ 772	$ 688	$ 772

Derivative and Hedging Instru46

Derivative and Hedging Instruments (Details-5) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016USD ($)counterparty	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)counterparty	Sep. 30, 2015USD ($)	Dec. 31, 2015USD ($)
Counterparties in net liability position or default [Abstract]
Derivative, net liability position of counterparties (less than $0.1 million)	$ 0		$ 0		$ 100
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	$ 45	$ 862	$ 1,469	$ 1,860
Commodity Derivative Contracts [Member] | Cost Of Gas Sold Expense [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	0	(17)	1,814	1,742
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	(703)	(233)	(635)	(607)
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		20,000
Maximum collateral that may be required to be posted	40,000		40,000
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	916	1,757	3,511	3,348
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

Rate Matters (Details)

Rate Matters (Details) - PSCW [Member] - MGE [Member] - USD ($)	1 Months Ended	4 Months Ended	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015	Sep. 30, 2016	Dec. 31, 2017	Dec. 31, 2015	Jul. 31, 2016	Jan. 31, 2016	Aug. 31, 2015
Rate Proceedings [Abstract]
Authorized return on equity, percentage					10.20%
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%
Electric Fuel Monitored Costs, 2016 [Member]
Fuel Rules [Abstract]
Change in fuel rules monitored costs							$ (14,800,000)
Deferred fuel rules monitored costs	$ 4,100,000		$ 4,100,000
Fuel Rules Credit ($0.00256/kWh), 2015/2016 [Member]
Fuel Rules [Abstract]
Electric fuel credit (per kWh)		$ 0.00256	0.00256
Electric fuel credit ($)								$ 10,900,000
Return of electric fuel credit, total		$ 2,600,000	$ 6,300,000
Fuel Rules Refund, 2015/2016 [Member]
Fuel Rules [Abstract]
Electric fuel credit ($)						$ 15,700,000
Return of electric fuel credit, total	$ 15,500,000
Electric Rate Proceeding [Member]
Rate Proceedings [Abstract]
Authorized rate increase (decrease), percentage			0.00%		3.80%
Authorized rate increase (decrease), amount			$ 0		$ 15,400,000
Electric Rate Proceeding [Member] | Proposed Future Rate Matters [Member]
Rate Proceedings [Abstract]
Proposed rate increase (decrease), percentage				1.70%
Gas Rate Proceeding [Member]
Rate Proceedings [Abstract]
Authorized rate increase (decrease), percentage			0.00%		(2.00%)
Authorized rate increase (decrease), amount			$ 0		$ (3,800,000)
Gas Rate Proceeding [Member] | Proposed Future Rate Matters [Member]
Rate Proceedings [Abstract]
Proposed rate increase (decrease), percentage				3.70%

Fair Value of Financial Instr48

Fair Value of Financial Instruments (Details-1) - USD ($) $ in Thousands		Sep. 30, 2016	Dec. 31, 2015
Carrying Amount [Member]
Assets:
Cash and cash equivalents		$ 111,585	$ 81,384
Liabilities:
Long-term debt	[1]	392,316	395,508
Unamortized discount and debt issuance costs, net		4,200	4,500
Fair Value [Member]
Assets:
Cash and cash equivalents		111,585	81,384
Liabilities:
Long-term debt	[1]	463,849	435,767
Unamortized discount and debt issuance costs, net		4,200	4,500
MGE [Member] | Carrying Amount [Member]
Assets:
Cash and cash equivalents		31,558	26,760
Liabilities:
Long-term debt	[1]	392,316	395,508
Unamortized discount and debt issuance costs, net		4,200	4,500
MGE [Member] | Fair Value [Member]
Assets:
Cash and cash equivalents		31,558	26,760
Liabilities:
Long-term debt	[1]	463,849	435,767
Unamortized discount and debt issuance costs, net		$ 4,200	$ 4,500
[1]	Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.2 million and $4.5 million at September 30, 2016, and December 31, 2015, respectively.

Fair Value of Financial Instr49

Fair Value of Financial Instruments (Details-2) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Liabilities:
Derivative liability, collateral offset		$ 1,000
Recurring [Member]
Assets:
Derivative assets, net	$ 1,367	234
Total Assets	1,887	993
Liabilities:
Derivative liabilities, net	50,938	54,316	[1]
Deferred compensation	2,963	3,145
Total liabilities	53,901	57,461
Recurring [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	520	759
Recurring [Member] | Level 1 [Member]
Assets:
Derivative assets, net	917	0
Total Assets	1,437	759
Liabilities:
Derivative liabilities, net	59	581	[1]
Deferred compensation	0	0
Total liabilities	59	581
Recurring [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	520	759
Recurring [Member] | Level 2 [Member]
Assets:
Derivative assets, net	0	0
Total Assets	0	0
Liabilities:
Derivative liabilities, net	0	0	[1]
Deferred compensation	2,963	3,145
Total liabilities	2,963	3,145
Recurring [Member] | Level 2 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0	0
Recurring [Member] | Level 3 [Member]
Assets:
Derivative assets, net	450	234
Total Assets	450	234
Liabilities:
Derivative liabilities, net	50,879	53,735	[1]
Deferred compensation	0	0
Total liabilities	50,879	53,735
Recurring [Member] | Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0	0
MGE [Member]
Liabilities:
Derivative liability, collateral offset		1,000
MGE [Member] | Recurring [Member]
Assets:
Derivative assets, net	1,367	234
Total Assets	1,464	382
Liabilities:
Derivative liabilities, net	50,938	54,316	[1]
Deferred compensation	2,963	3,145
Total liabilities	53,901	57,461
MGE [Member] | Recurring [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	97	148
MGE [Member] | Recurring [Member] | Level 1 [Member]
Assets:
Derivative assets, net	917	0
Total Assets	1,014	148
Liabilities:
Derivative liabilities, net	59	581	[1]
Deferred compensation	0	0
Total liabilities	59	581
MGE [Member] | Recurring [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	97	148
MGE [Member] | Recurring [Member] | Level 2 [Member]
Assets:
Derivative assets, net	0	0
Total Assets	0	0
Liabilities:
Derivative liabilities, net	0	0	[1]
Deferred compensation	2,963	3,145
Total liabilities	2,963	3,145
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:
Derivative assets, net	450	234
Total Assets	450	234
Liabilities:
Derivative liabilities, net	50,879	53,735	[1]
Deferred compensation	0	0
Total liabilities	50,879	53,735
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 $1.0 million of collateral that was posted against derivative positions with counterparties as of December 31, 2015.

Fair Value of Financial Instr50

Fair Value of Financial Instruments (Details-3)	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Basis adjustment:
Basis adjustment - on peak	93.30%	96.90%
Basis adjustment - off peak	94.10%	95.10%
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	55.00%	60.00%
Purchased power	45.00%	40.00%
Maximum [Member]
Counterparty fuel mix:
Internal generation	75.00%	75.00%
Purchased power	25.00%	25.00%

Fair Value of Financial Instr51

Fair Value of Financial Instruments (Details-4) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance,		$ (51,883)	$ (56,194)	$ (53,501)	$ (53,986)
Realized and unrealized gains (losses):
Included in regulatory (assets) liabilities		1,455	(888)	3,073	(3,096)
Included in other comprehensive income		0	0	0	0
Included in earnings	[1]	(278)	(2,285)	(4,250)	(4,497)
Included in current assets		0	0	0	0
Purchases		5,814	6,364	16,751	17,497
Sales		0	0	0	0
Issuances		0	0	0	0
Settlements		(5,537)	(4,079)	(12,502)	(13,000)
Transfers in and/or out of level 3		0	0	0	0
Ending balance,		(50,429)	(57,082)	(50,429)	(57,082)
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities	[1]	0	0	0	0
Purchased Power Expense [Member]
Realized and unrealized gains (losses):
Included in earnings	[1]	(278)	(2,302)	(4,250)	(4,515)
Cost Of Gas Sold Expense [Member]
Realized and unrealized gains (losses):
Included in earnings	[1]	$ 0	$ 17	$ 0	$ 18
[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.

New Accounting Pronouncements (

New Accounting Pronouncements (Details-1) - Accounting Standards Update 2015-03 - Simplifying the Presentation of Debt Issuance Costs [Member] - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Other deferred charges [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New accounting pronouncement, effect of adoption, decrease in assets and liabilities (debt issuance costs)	$ 4	$ 4.3
Long-term debt [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New accounting pronouncement, effect of adoption, decrease in assets and liabilities (debt issuance costs)	$ 4	$ 4.3

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Segment Reporting Information [Line Items]
Operating revenues		$ 136,717	$ 140,795	$ 405,820	$ 433,055
Depreciation and amortization		(11,212)	(11,182)	(33,358)	(33,026)
Other operating expenses		(78,978)	(83,436)	(268,192)	(297,952)
Operating income (loss)		46,527	46,177	104,270	102,077
Other income (deductions), net		2,105	2,564	6,726	7,115
Interest (expense) income, net		(5,038)	(5,036)	(14,995)	(15,135)
Income before income taxes		43,594	43,705	96,001	94,057
Income tax (provision) benefit		(15,714)	(15,351)	(34,943)	(33,946)
Net Income (Loss)		27,880	28,354	61,058	60,111
Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		118,933	121,453	312,470	319,174
Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		17,570	17,431	92,368	108,028
Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		214	1,911	982	5,853
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		136,717	140,795	405,820	433,055
Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		119,392	121,616	313,952	319,574
Depreciation and amortization		(7,332)	(7,584)	(21,754)	(22,372)
Other operating expenses		(77,010)	(80,202)	(230,680)	(239,963)
Operating income (loss)		35,050	33,830	61,518	57,239
Other income (deductions), net		178	141	492	247
Interest (expense) income, net		(2,855)	(2,798)	(8,421)	(8,385)
Income before income taxes		32,373	31,173	53,589	49,101
Income tax (provision) benefit		(11,290)	(10,321)	(17,984)	(15,868)
Net Income (Loss)		21,083	20,852	35,605	33,233
Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		23,610	21,286	109,646	116,899
Depreciation and amortization		(2,047)	(1,714)	(6,043)	(5,018)
Other operating expenses		(19,292)	(16,906)	(88,328)	(96,063)
Operating income (loss)		2,271	2,666	15,275	15,818
Other income (deductions), net		13	(7)	(13)	(33)
Interest (expense) income, net		(818)	(804)	(2,425)	(2,398)
Income before income taxes		1,466	1,855	12,837	13,387
Income tax (provision) benefit		(494)	(732)	(5,048)	(5,370)
Net Income (Loss)		972	1,123	7,789	8,017
Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		11,212	11,777	33,876	35,419
Depreciation and amortization		(1,833)	(1,872)	(5,537)	(5,601)
Other operating expenses		(33)	(36)	(115)	(122)
Operating income (loss)		9,346	9,869	28,224	29,696
Other income (deductions), net		0	0	0	0
Interest (expense) income, net		(1,436)	(1,491)	(4,348)	(4,516)
Income before income taxes		7,910	8,378	23,876	25,180
Income tax (provision) benefit		(3,175)	(3,362)	(9,583)	(10,106)
Net Income (Loss)		4,735	5,016	14,293	15,074
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		(13)	(15)	(17)	(15)
Operating income (loss)		(13)	(15)	(17)	(15)
Other income (deductions), net		2,023	2,397	6,023	6,568
Interest (expense) income, net		0	0	0	0
Income before income taxes		2,010	2,382	6,006	6,553
Income tax (provision) benefit		(812)	(962)	(2,418)	(2,637)
Net Income (Loss)		1,198	1,420	3,588	3,916
Operating Segments [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues		0	0	0	0
Depreciation and amortization		0	(12)	(24)	(35)
Other operating expenses		(127)	(161)	(706)	(626)
Operating income (loss)		(127)	(173)	(730)	(661)
Other income (deductions), net		(109)	33	224	333
Interest (expense) income, net		71	57	199	164
Income before income taxes		(165)	(83)	(307)	(164)
Income tax (provision) benefit		57	26	90	35
Net Income (Loss)		(108)	(57)	(217)	(129)
Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues		(17,497)	(13,884)	(51,654)	(38,837)
Depreciation and amortization		0	0	0	0
Other operating expenses		17,497	13,884	51,654	38,837
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 (Loss)		0	0	0	0
Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		459	163	1,482	400
Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		6,040	3,855	17,278	8,871
Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		10,998	9,866	32,894	29,566
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		136,728	140,806	405,860	433,083
Depreciation and amortization		(11,212)	(11,170)	(33,334)	(32,991)
Other operating expenses	[1]	(93,781)	(97,686)	(299,998)	(328,571)
Operating income (loss)	[1]	31,735	31,950	72,528	71,521
Other income (deductions), net	[1]	1,036	1,554	3,615	4,018
Interest (expense) income, net		(5,109)	(5,093)	(15,194)	(15,299)
Income tax (provision) benefit		(14,934)	(14,401)	(32,488)	(31,218)
Net Income Including Noncontrolling Interest		27,662	28,411	60,949	60,240
Less Net Income Attributable to Noncontrolling Interest, net of tax		(5,695)	(6,633)	(17,899)	(19,812)
Net Income (Loss)		21,967	21,778	43,050	40,428
MGE [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		118,938	121,460	312,488	319,191
MGE [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		17,576	17,435	92,390	108,039
MGE [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		214	1,911	982	5,853
MGE [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	[2]	0	0	0	0
MGE [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues		136,728	140,806	405,860	433,083
MGE [Member] | Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		119,392	121,616	313,952	319,574
Depreciation and amortization		(7,332)	(7,584)	(21,754)	(22,372)
Other operating expenses	[1]	(88,282)	(90,511)	(248,566)	(255,732)
Operating income (loss)	[1]	23,778	23,521	43,632	41,470
Other income (deductions), net	[1]	160	129	394	148
Interest (expense) income, net		(2,855)	(2,798)	(8,421)	(8,385)
Net Income Including Noncontrolling Interest		21,083	20,852	35,605	33,233
Less Net Income Attributable to Noncontrolling Interest, net of tax		0	0	0	0
Net Income (Loss)		21,083	20,852	35,605	33,233
MGE [Member] | Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		23,610	21,286	109,646	116,899
Depreciation and amortization		(2,047)	(1,714)	(6,043)	(5,018)
Other operating expenses	[1]	(19,781)	(17,635)	(93,348)	(101,405)
Operating income (loss)	[1]	1,782	1,937	10,255	10,476
Other income (deductions), net	[1]	8	(10)	(41)	(61)
Interest (expense) income, net		(818)	(804)	(2,425)	(2,398)
Net Income Including Noncontrolling Interest		972	1,123	7,789	8,017
Less Net Income Attributable to Noncontrolling Interest, net of tax		0	0	0	0
Net Income (Loss)		972	1,123	7,789	8,017
MGE [Member] | Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		11,212	11,777	33,876	35,419
Depreciation and amortization		(1,833)	(1,872)	(5,537)	(5,601)
Other operating expenses	[1]	(3,208)	(3,398)	(9,698)	(10,228)
Operating income (loss)	[1]	6,171	6,507	18,641	19,590
Other income (deductions), net	[1]	0	0	0	0
Interest (expense) income, net		(1,436)	(1,491)	(4,348)	(4,516)
Net Income Including Noncontrolling Interest		4,735	5,016	14,293	15,074
Less Net Income Attributable to Noncontrolling Interest, net of tax		0	0	0	0
Net Income (Loss)		4,735	5,016	14,293	15,074
MGE [Member] | Operating Segments [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	[2]	0	0	0	0
Depreciation and amortization	[2]	0	0	0	0
Other operating expenses	[1],[2]	4	(15)	0	(15)
Operating income (loss)	[1],[2]	4	(15)	0	(15)
Other income (deductions), net	[1],[2]	868	1,435	3,262	3,931
Interest (expense) income, net	[2]	0	0	0	0
Net Income Including Noncontrolling Interest	[2]	872	1,420	3,262	3,916
Less Net Income Attributable to Noncontrolling Interest, net of tax	[2]	0	0	0	0
Net Income (Loss)	[2]	872	1,420	3,262	3,916
MGE [Member] | Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues		(17,486)	(13,873)	(51,614)	(38,809)
Depreciation and amortization		0	0	0	0
Other operating expenses	[1]	17,486	13,873	51,614	38,809
Operating income (loss)	[1]	0	0	0	0
Other income (deductions), net	[1]	0	0	0	0
Interest (expense) income, net		0	0	0	0
Net Income Including Noncontrolling Interest		0	0	0	0
Less Net Income Attributable to Noncontrolling Interest, net of tax		(5,695)	(6,633)	(17,899)	(19,812)
Net Income (Loss)		(5,695)	(6,633)	(17,899)	(19,812)
MGE [Member] | Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		454	156	1,464	383
MGE [Member] | Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		6,034	3,851	17,256	8,860
MGE [Member] | Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		10,998	9,866	32,894	29,566
MGE [Member] | Consolidation Elimination Entries [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	[2]	$ 0	$ 0	$ 0	$ 0
[1]	Amounts are shown net of the related tax expense, consistent with the presentation on the MGE Consolidated Statement of Income.
[2]	As of July 31, 2016, MGE no longer consolidates MGE Energy's proportionate share of equity earnings in MGE Transco. See Footnote 3 for further discussion.