Document and Entity Information
Document and Entity Information - USD ($) | 12 Months Ended | ||
Dec. 31, 2021 | Jan. 31, 2022 | Jun. 30, 2021 | |
Document and Entity Information [Line Items] | |||
Entity Registrant Name | MGE Energy, Inc. | ||
Entity Central Index Key | 0001161728 | ||
Document Type | 10-K | ||
Document Period End Date | Dec. 31, 2021 | ||
Amendment Flag | false | ||
Trading Symbol | MGEE | ||
Document Fiscal Year Focus | 2021 | ||
Document Fiscal Period Focus | FY | ||
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 Public Float | $ 2,686,237,656 | ||
Entity Common Stock Shares Outstanding | 36,163,370 | ||
Entity Emerging Growth Company | false | ||
Entity Small Business | false | ||
ICFR Auditor Attestation Flag | true | ||
Entity Shell Company | false | ||
Entity Interactive Data Current | Yes | ||
Security Exchange Name | NASDAQ | ||
Security 12(b) Title | Common Stock, $1 Par Value Per Share | ||
Entity Tax Identification Number | 39-2040501 | ||
Entity File Number | 000-49965 | ||
Entity Incorporation State Country Code | WI | ||
Entity Address Address Line 1 | 133 South Blair Street | ||
Entity Address City Or Town | Madison | ||
Entity Address State Or Province | WI | ||
Entity Address Postal Zip Code | 53788 | ||
City Area Code | 608 | ||
Local Phone Number | 252-7000 | ||
Document Transition Report | false | ||
Document Annual Report | true | ||
Documents Incorporated By Reference | DOCUMENTS INCORPORATED BY REFERENCE Portions of MGE Energy, Inc.'s definitive proxy statement to be filed before April 30, 2022 , relating to its annual meeting of shareholders, are incorporated by reference into Part III of this annual report on Form 10-K. | ||
Auditor Name | PricewaterhouseCoopers LLP | ||
Auditor Location | Chicago, Illinois | ||
Auditor Firm ID | 238 | ||
MGE [Member] | |||
Document and Entity Information [Line Items] | |||
Entity Registrant Name | Madison Gas and Electric Company | ||
Entity Central Index Key | 0000061339 | ||
Entity Well known Seasoned Issuer | Yes | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Filer Category | Non-accelerated Filer | ||
Entity Public Float | $ 0 | ||
Entity Common Stock Shares Outstanding | 17,347,894 | ||
Entity Emerging Growth Company | false | ||
Entity Small Business | false | ||
Entity Shell Company | false | ||
Entity Interactive Data Current | Yes | ||
Entity Tax Identification Number | 39-0444025 | ||
Entity File Number | 000-1125 | ||
Entity Incorporation State Country Code | WI | ||
Entity Address Address Line 1 | 133 South Blair Street | ||
Entity Address City Or Town | Madison | ||
Entity Address State Or Province | WI | ||
Entity Address Postal Zip Code | 53788 | ||
City Area Code | 608 | ||
Local Phone Number | 252-7000 | ||
Document Transition Report | false | ||
Document Annual Report | true | ||
Auditor Name | PricewaterhouseCoopers LLP | ||
Auditor Location | Chicago, Illinois | ||
Auditor Firm ID | 238 |
Consolidated Statements of Inco
Consolidated Statements of Income - USD ($) shares in Thousands, $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Operating Revenues: | |||
Electric revenues | $ 420,964 | $ 394,372 | $ 408,980 |
Gas revenues | 185,620 | 144,261 | 159,875 |
Total Operating Revenues | 606,584 | 538,633 | 568,855 |
Operating Expenses: | |||
Fuel for electric generation | 54,633 | 41,684 | 51,954 |
Purchased power | 39,395 | 42,883 | 41,474 |
Cost of gas sold | 99,690 | 63,697 | 79,775 |
Other operations and maintenance | 199,316 | 186,430 | 193,322 |
Depreciation and amortization | 76,983 | 74,188 | 71,562 |
Other general taxes | 19,273 | 19,754 | 19,858 |
Total Operating Expenses | 489,290 | 428,636 | 457,945 |
Operating Income | 117,294 | 109,997 | 110,910 |
Other income, net | 16,694 | 25,365 | 18,811 |
Interest expense, net | (24,112) | (23,521) | (23,063) |
Income before income taxes | 109,876 | 111,841 | 106,658 |
Income tax provision | (4,115) | (19,423) | (19,784) |
Net Income Including Noncontrolling Interest | 105,761 | 92,418 | 86,874 |
Net Income | $ 105,761 | $ 92,418 | $ 86,874 |
Earnings Per Share of Common Stock Basic | $ 2.92 | $ 2.60 | $ 2.51 |
Earnings Per Share of Common Stock Diluted | 2.92 | 2.60 | 2.51 |
Dividends per share of common stock | $ 1.52 | $ 1.45 | $ 1.38 |
Weighted Average Shares Outstanding Basic | 36,163 | 35,612 | 34,668 |
Weighted Average Shares Outstanding Diluted | 36,167 | 35,612 | 34,668 |
MGE [Member] | |||
Operating Revenues: | |||
Electric revenues | $ 420,964 | $ 394,372 | $ 408,980 |
Gas revenues | 185,620 | 144,261 | 159,875 |
Total Operating Revenues | 606,584 | 538,633 | 568,855 |
Operating Expenses: | |||
Fuel for electric generation | 54,633 | 41,684 | 51,954 |
Purchased power | 39,395 | 42,883 | 41,474 |
Cost of gas sold | 99,690 | 63,697 | 79,775 |
Other operations and maintenance | 198,552 | 185,450 | 192,440 |
Depreciation and amortization | 76,983 | 74,188 | 71,562 |
Other general taxes | 19,269 | 19,750 | 19,858 |
Total Operating Expenses | 488,522 | 427,652 | 457,063 |
Operating Income | 118,062 | 110,981 | 111,792 |
Other income, net | 9,121 | 15,019 | 10,703 |
Interest expense, net | (24,153) | (23,642) | (24,298) |
Income before income taxes | 103,030 | 102,358 | 98,197 |
Income tax provision | (2,248) | (16,835) | (17,418) |
Net Income Including Noncontrolling Interest | 100,782 | 85,523 | 80,779 |
Less Net Income Attributable to Noncontrolling Interest, net of tax | (22,391) | (22,393) | (22,349) |
Net Income | $ 78,391 | $ 63,130 | $ 58,430 |
Consolidated Statements of Cash
Consolidated Statements of Cash Flows - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Operating Activities: | |||
Net Income | $ 105,761 | $ 92,418 | $ 86,874 |
Items not affecting cash: | |||
Depreciation and amortization | 76,983 | 74,188 | 71,562 |
Deferred income taxes | 4,837 | 10,363 | 7,212 |
Provision for doubtful receivables | 1,550 | 1,415 | 1,615 |
Employee benefit plan (credit) cost | (2,203) | (3,716) | (3,813) |
Equity earnings in investments | (9,270) | (10,221) | (9,889) |
Other items | 120 | (2,750) | 163 |
Changes in working capital items: | |||
Accounts receivable and unbilled revenues (change) | (24,651) | (5,451) | 1,060 |
Inventories (change) | (6,342) | (842) | (3,420) |
Prepaid taxes (change) | (5,035) | 1,713 | (677) |
Other current assets (change) | (192) | (1,057) | 29 |
Accounts payable (change) | 2,729 | 14,353 | (7,432) |
Other current liabilities (change) | (6,734) | (5,635) | (10,264) |
Dividends from investment | 7,832 | 8,998 | 7,347 |
Cash contributions to pension and other postretirement plans | (6,935) | (6,296) | (5,714) |
Other noncurrent items, net | (923) | 4,963 | (4,178) |
Cash Provided by Operating Activities | 137,527 | 172,443 | 130,475 |
Investing Activities: | |||
Capital expenditures | (153,169) | (203,139) | (164,036) |
Capital contributions to investments | (4,027) | (5,601) | (7,813) |
Other | 221 | (1,672) | (508) |
Cash Used for Investing Activities | (156,975) | (210,412) | (172,357) |
Financing Activities: | |||
Issuance of common stock, net | 0 | 79,635 | 0 |
Cash dividends paid on common stock | (54,788) | (51,729) | (47,842) |
Repayment of long-term debt | (4,771) | (38,959) | (4,553) |
Issuance of long-term debt | 100,000 | 19,300 | 50,000 |
Proceeds from (Repayments of) short-term debt | (47,000) | 52,500 | (13,000) |
Other | (2,197) | (1,553) | (1,838) |
Cash Provided by (Used for) Financing Activities | (8,756) | 59,194 | (17,233) |
Change in cash, cash equivalents, and restricted cash: | (28,204) | 21,225 | (59,115) |
Cash, cash equivalents, and restricted cash at beginning of period | 47,039 | 25,814 | 84,929 |
Cash, cash equivalents, and restricted cash at end of period | 18,835 | 47,039 | 25,814 |
Supplemental disclosures of cash flow information: | |||
Interest paid | 23,502 | 23,898 | 23,171 |
Income taxes paid | 4,000 | 8,127 | 14,617 |
Income taxes received | 0 | 0 | (255) |
Significant noncash investing activities: | |||
Accrued capital expenditures | 14,414 | 5,719 | 26,697 |
MGE [Member] | |||
Operating Activities: | |||
Net Income | 100,782 | 85,523 | 80,779 |
Items not affecting cash: | |||
Depreciation and amortization | 76,983 | 74,188 | 71,562 |
Deferred income taxes | 3,654 | 8,543 | 5,286 |
Provision for doubtful receivables | 1,550 | 1,415 | 1,615 |
Employee benefit plan (credit) cost | (2,203) | (3,716) | (3,813) |
Other items | 2,002 | (1,828) | 1,256 |
Changes in working capital items: | |||
Accounts receivable and unbilled revenues (change) | (24,680) | (5,453) | 1,060 |
Inventories (change) | (6,342) | (842) | (3,420) |
Prepaid taxes (change) | (4,531) | 616 | 327 |
Other current assets (change) | (148) | (1,157) | 147 |
Accounts payable (change) | 2,775 | 14,603 | (7,754) |
Accrued interest and taxes (change) | 244 | 1,651 | (1,565) |
Other current liabilities (change) | (11,107) | (4,909) | (9,618) |
Cash contributions to pension and other postretirement plans | (6,935) | (6,296) | (5,714) |
Other noncurrent items, net | (1,804) | 3,980 | (4,278) |
Cash Provided by Operating Activities | 130,240 | 166,318 | 125,870 |
Investing Activities: | |||
Capital expenditures | (153,169) | (203,139) | (164,036) |
Other | (1,709) | (2,122) | (782) |
Cash Used for Investing Activities | (154,878) | (205,261) | (164,818) |
Financing Activities: | |||
Cash dividends paid to parent by MGE | (5,000) | 0 | 0 |
Distributions to parent from noncontrolling interest | (15,000) | (21,500) | (23,500) |
Capital contributions from parent | 0 | 30,000 | 30,500 |
Repayment of long-term debt | (4,771) | (38,959) | (4,553) |
Issuance of long-term debt | 100,000 | 19,300 | 50,000 |
Proceeds from (Repayments of) short-term debt | (47,000) | 52,500 | (13,000) |
Other | (2,197) | (1,523) | (1,640) |
Cash Provided by (Used for) Financing Activities | 26,032 | 39,818 | 37,807 |
Change in cash, cash equivalents, and restricted cash: | 1,394 | 875 | (1,141) |
Cash, cash equivalents, and restricted cash at beginning of period | 6,404 | 5,529 | 6,670 |
Cash, cash equivalents, and restricted cash at end of period | 7,798 | 6,404 | 5,529 |
Supplemental disclosures of cash flow information: | |||
Interest paid | 23,502 | 23,898 | 23,171 |
Income taxes paid | 0 | 0 | 95 |
Income taxes received | 0 | 0 | (249) |
Significant noncash investing activities: | |||
Accrued capital expenditures | $ 14,414 | $ 5,719 | $ 26,697 |
Consolidated Balance Sheets
Consolidated Balance Sheets - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 | |
Current Assets: | |||
Cash and cash equivalents | $ 17,438 | $ 44,738 | |
Accounts receivable, less reserves | 46,205 | 41,384 | |
Other accounts receivables, less reserves | 16,094 | 7,300 | |
Unbilled revenues | 34,812 | 27,511 | |
Materials and supplies, at average cost | 29,863 | 32,513 | |
Fuel for electric generation, at average cost | 6,429 | 6,356 | |
Stored natural gas, at average cost | 15,668 | 8,396 | |
Prepaid taxes | 20,214 | 15,179 | |
Regulatory assets - current | 1,465 | 14,748 | |
Other current assets | 11,183 | 11,394 | |
Total Current Assets | 199,371 | 209,519 | |
Other long-term receivables | 1,155 | 1,435 | |
Regulatory assets | 107,547 | 142,504 | |
Pension and other postretirement benefit asset | 58,757 | 13,873 | |
Other deferred assets and other | 27,548 | 22,259 | |
Property, Plant, and Equipment: | |||
In-service utility plant, net | 1,828,171 | 1,630,286 | |
Construction work in progress | 50,603 | 139,099 | |
Total Property, Plant, and Equipment | 1,878,774 | 1,769,385 | |
Investments | 98,754 | 94,676 | |
Total Assets | 2,371,906 | 2,253,651 | |
Current Liabilities: | |||
Long-term debt due within one year | 4,889 | 4,771 | |
Short-term debt | [1] | 5,500 | 52,500 |
Accounts payable | 64,149 | 54,642 | |
Accrued interest and taxes | 10,385 | 8,539 | |
Accrued payroll related items | 12,951 | 12,635 | |
Regulatory liabilities - current | 9,365 | 41,664 | |
Derivative liabilities | 2,140 | 10,160 | |
Other current liabilities | 8,468 | 6,015 | |
Total Current Liabilities | 117,847 | 190,926 | |
Other Credits: | |||
Deferred income taxes | 231,149 | 231,471 | |
Investment tax credit - deferred | 44,836 | 21,821 | |
Regulatory liabilities | 154,298 | 142,239 | |
Accrued pension and other postretirement benefits | 73,085 | 78,168 | |
Derivative liabilities | 0 | 3,980 | |
Finance lease liabilities | 17,322 | 17,532 | |
Other deferred liabilities and other | 91,690 | 72,211 | |
Total Other Credits | 612,380 | 567,422 | |
Common shareholders' equity: | |||
Common stock | 36,163 | 36,163 | |
Additional paid-in capital | 394,903 | 394,408 | |
Retained earnings | 596,402 | 545,429 | |
Total Common Shareholders' Equity | 1,027,468 | 976,000 | |
Long-term debt | 614,211 | 519,303 | |
Total Capitalization | 1,641,679 | 1,495,303 | |
Commitments and contingencies (see Footnote 16) | |||
Total Liabilities and Capitalization | 2,371,906 | 2,253,651 | |
MGE [Member] | |||
Current Assets: | |||
Cash and cash equivalents | 6,401 | 4,103 | |
Accounts receivable, less reserves | 46,205 | 41,384 | |
Affiliate receivables | 558 | 532 | |
Other accounts receivables, less reserves | 16,092 | 7,295 | |
Unbilled revenues | 34,812 | 27,511 | |
Materials and supplies, at average cost | 29,863 | 32,513 | |
Fuel for electric generation, at average cost | 6,429 | 6,356 | |
Stored natural gas, at average cost | 15,668 | 8,396 | |
Prepaid taxes | 19,379 | 14,848 | |
Regulatory assets - current | 1,465 | 14,748 | |
Other current assets | 11,071 | 11,326 | |
Total Current Assets | 187,943 | 169,012 | |
Affiliate receivable long-term | 1,589 | 2,118 | |
Regulatory assets | 107,547 | 142,504 | |
Pension and other postretirement benefit asset | 58,757 | 13,873 | |
Other deferred assets and other | 27,907 | 22,448 | |
Property, Plant, and Equipment: | |||
In-service utility plant, net | 1,828,199 | 1,630,314 | |
Construction work in progress | 50,603 | 139,099 | |
Total Property, Plant, and Equipment | 1,878,802 | 1,769,413 | |
Investments | 230 | 603 | |
Total Assets | 2,262,775 | 2,119,971 | |
Current Liabilities: | |||
Long-term debt due within one year | 4,889 | 4,771 | |
Short-term debt | 5,500 | 52,500 | |
Accounts payable | 64,130 | 54,576 | |
Accrued interest and taxes | 10,649 | 10,405 | |
Accrued payroll related items | 12,951 | 12,635 | |
Regulatory liabilities - current | 9,365 | 41,664 | |
Derivative liabilities | 2,140 | 10,160 | |
Other current liabilities | 5,968 | 6,042 | |
Total Current Liabilities | 115,592 | 192,753 | |
Other Credits: | |||
Deferred income taxes | 198,885 | 200,390 | |
Investment tax credit - deferred | 44,836 | 21,821 | |
Regulatory liabilities | 154,298 | 142,239 | |
Accrued pension and other postretirement benefits | 73,085 | 78,168 | |
Derivative liabilities | 0 | 3,980 | |
Finance lease liabilities | 17,322 | 17,532 | |
Other deferred liabilities and other | 92,152 | 72,173 | |
Total Other Credits | 580,578 | 536,303 | |
Common shareholders' equity: | |||
Common stock | 17,348 | 17,348 | |
Additional paid-in capital | 252,917 | 252,917 | |
Retained earnings | 533,542 | 460,151 | |
Total Common Shareholders' Equity | 803,807 | 730,416 | |
Noncontrolling interest | 148,587 | 141,196 | |
Total Equity | 952,394 | 871,612 | |
Long-term debt | 614,211 | 519,303 | |
Total Capitalization | 1,566,605 | 1,390,915 | |
Commitments and contingencies (see Footnote 16) | |||
Total Liabilities and Capitalization | $ 2,262,775 | $ 2,119,971 | |
[1] | MGE Energy short-term borrowings include MGE Energy and MGE lines of credit and MGE commercial paper. |
Consolidated Balance Sheets (Pa
Consolidated Balance Sheets (Parentheticals) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 |
Receivables, Net | ||
Reserve for uncollectible accounts receivable | $ 6,940 | $ 5,787 |
Reserve for uncollectible other accounts receivable | $ 1,364 | $ 1,290 |
Common shareholders' equity | ||
Common stock, par value | $ 1 | $ 1 |
Common stock, shares authorized | 75,000,000 | 75,000,000 |
Common stock, shares issued | 36,163,000 | 36,163,000 |
Common stock, shares outstanding | 36,163,000 | 36,163,000 |
MGE [Member] | ||
Receivables, Net | ||
Reserve for uncollectible accounts receivable | $ 6,940 | $ 5,787 |
Reserve for uncollectible other accounts receivable | $ 1,364 | $ 1,290 |
Common shareholders' equity | ||
Common stock, par value | $ 1 | $ 1 |
Common stock, shares authorized | 50,000,000 | 50,000,000 |
Common stock, shares outstanding | 17,348,000 | 17,348,000 |
MGE Energy Inc Consolidated Sta
MGE Energy Inc Consolidated Statements of Common Equity - USD ($) $ in Thousands | Total | Common Stock [Member] | Additional Paid-In Capital [Member] | Retained Earnings [Member] | Accumulated Other Comprehensive (Loss)/ Income [Member] |
Beginning balance, shares at Dec. 31, 2018 | 34,668,000 | ||||
Beginning balance, value at Dec. 31, 2018 | $ 816,644 | $ 34,668 | $ 316,268 | $ 465,708 | $ 0 |
Increase (Decrease) in Equity [Roll Forward] | |||||
Net Income | 86,874 | 86,874 | |||
Common stock dividends declared | (47,842) | (47,842) | |||
Issuance of common stock, net | 0 | ||||
Ending balance, shares at Dec. 31, 2019 | 34,668,000 | ||||
Ending balance, value at Dec. 31, 2019 | 855,676 | $ 34,668 | 316,268 | 504,740 | 0 |
Increase (Decrease) in Equity [Roll Forward] | |||||
Net Income | 92,418 | 92,418 | |||
Common stock dividends declared | $ (51,729) | (51,729) | |||
Common stock issued during period | 1,500,000 | 1,495,000 | |||
Issuance of common stock, net | $ 79,635 | $ 1,495 | 78,140 | ||
Ending balance, shares at Dec. 31, 2020 | 36,163,000 | ||||
Ending balance, value at Dec. 31, 2020 | 976,000 | $ 36,163 | 394,408 | 545,429 | 0 |
Increase (Decrease) in Equity [Roll Forward] | |||||
Net Income | 105,761 | 105,761 | |||
Common stock dividends declared | (54,788) | 54,788 | |||
Issuance of common stock, net | 0 | ||||
Equity-based compensation plans and other | 495 | 495 | |||
Ending balance, shares at Dec. 31, 2021 | 36,163,000 | ||||
Ending balance, value at Dec. 31, 2021 | $ 1,027,468 | $ 36,163 | $ 394,903 | $ 596,402 | $ 0 |
MGE Energy Inc - Consolidated S
MGE Energy Inc - Consolidated Statements of Common Equity (Parentheticals) - $ / shares | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Dividends per share of common stock | $ 1.52 | $ 1.45 | $ 1.38 |
Madison Gas and Electric Compan
Madison Gas and Electric Company Consolidated Statements of Equity - USD ($) $ in Thousands | Total | MGE [Member] | Common Stock [Member] | Common Stock [Member]MGE [Member] | Additional Paid-In Capital [Member]MGE [Member] | Retained Earnings [Member]MGE [Member] | Accumulated Other Comprehensive (Loss)/ Income [Member]MGE [Member] | Noncontrolling Interest [Member]MGE [Member] |
Beginning balance, shares at Dec. 31, 2018 | 34,668,000 | 17,348,000 | ||||||
Beginning balance, value at Dec. 31, 2018 | $ 689,810 | $ 17,348 | $ 192,417 | $ 338,591 | $ 0 | $ 141,454 | ||
Increase (Decrease) in Equity [Roll Forward] | ||||||||
Net Income | $ 86,874 | 80,779 | 58,430 | 22,349 | ||||
Capital contributions from parent | 30,500 | 30,500 | ||||||
Cash dividends paid to parent by MGE | 0 | |||||||
Distributions to parent from noncontrolling interest | (23,500) | (23,500) | ||||||
Ending balance, shares at Dec. 31, 2019 | 34,668,000 | 17,348,000 | ||||||
Ending balance, value at Dec. 31, 2019 | 777,589 | $ 17,348 | 222,917 | 397,021 | 0 | 140,303 | ||
Increase (Decrease) in Equity [Roll Forward] | ||||||||
Net Income | 92,418 | 85,523 | 63,130 | 22,393 | ||||
Capital contributions from parent | 30,000 | 30,000 | ||||||
Cash dividends paid to parent by MGE | 0 | |||||||
Distributions to parent from noncontrolling interest | (21,500) | (21,500) | ||||||
Ending balance, shares at Dec. 31, 2020 | 36,163,000 | 17,348,000 | ||||||
Ending balance, value at Dec. 31, 2020 | 871,612 | $ 17,348 | 252,917 | 460,151 | 0 | 141,196 | ||
Increase (Decrease) in Equity [Roll Forward] | ||||||||
Net Income | $ 105,761 | 100,782 | 78,391 | 22,391 | ||||
Capital contributions from parent | 0 | |||||||
Cash dividends paid to parent by MGE | (5,000) | (5,000) | ||||||
Distributions to parent from noncontrolling interest | (15,000) | (15,000) | ||||||
Ending balance, shares at Dec. 31, 2021 | 36,163,000 | 17,348,000 | ||||||
Ending balance, value at Dec. 31, 2021 | $ 952,394 | $ 17,348 | $ 252,917 | $ 533,542 | $ 0 | $ 148,587 |
Summary of Significant Accounti
Summary of Significant Accounting Policies | 12 Months Ended |
Dec. 31, 2021 | |
Accounting Policies [Abstract] | |
Summary of Significant Accounting Policies | 1. Summary of Sign ificant Accounting Policies. a. Basis of Presentation - MGE Energy and MGE. The consolidated financial statements are prepared in conformity with accounting principles generally accepted in the United States of America (GAAP), which give recognition to the rate making accounting policies for regulated operations prescribed by the regulatory authorities having jurisdiction, principally the PSCW and FERC. MGE's accounting records conform to the FERC uniform system of accounts. b. Principles of Consolidation - MGE Energy and MGE. MGE, a wholly owned subsidiary of MGE Energy, is a regulated electric and gas utility headquartered in Madison, Wisconsin. MGE Energy and MGE consolidate all majority owned subsidiaries in which they have a controlling influence. Additional wholly owned subsidiaries of MGE Energy include CWDC, MAGAEL, MGE Power, MGE State Energy Services, MGE Services, MGE Transco, and MGEE Transco. CWDC owns 100 % of North Mendota, a subsidiary created to serve as a development entity for property. MGE Power owns 100 % of MGE Power Elm Road and MGE Power West Campus. MGE Power and its subsidiaries are part of MGE Energy's nonregulated energy operations, which were formed to own and lease electric generation projects to assist MGE. MGE Transco and MGEE Transco are nonregulated entities formed to own the investments in ATC and ATC Holdco, respectively. MGE did not own any subsidiaries as of December 31, 2021. MGE Energy and MGE consolidate variable interest entities (VIEs) for which it is the primary beneficiary. Variable interest entities are legal entities that possess any of the following characteristics: equity investors who have an insufficient amount of equity at risk to finance their activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or equity holders who do not receive expected losses or returns significant to the VIE. If MGE Energy or MGE is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, all relevant facts and circumstances are considered, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. Ongoing reassessments of all VIEs are performed to determine if the primary beneficiary status has changed. MGE has consolidated MGE Power Elm Road and MGE Power West Campus. Both entities are VIEs. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. See Footnote 3 for more discussion of these entities. The consolidated financial statements reflect the application of certain accounting policies described in this note. All intercompany accounts and transactions have been eliminated in consolidation. c. Use of Estimates - MGE Energy and MGE. In order to prepare consolidated financial statements in conformity with GAAP, management must make estimates and assumptions. These estimates could affect reported amounts of assets, liabilities, and disclosures at the date of the financial statements, as well as the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from management's estimates. MGE Energy and MGE continues to assess the presence of COVID-19 developments and its impact on the assumptions and estimates used in the preparation of these financial statements. d. Cash, Cash Equivalents, and Restricted Cash – MGE Energy and MGE. The following table presents the components of total cash, cash equivalents, and restricted cash on the consolidated balance sheets. (In thousands) MGE Energy MGE As of December 31, 2021 2020 2021 2020 Cash and cash equivalents $ 17,438 $ 44,738 $ 6,401 $ 4,103 Restricted cash 847 644 847 644 Receivable - margin account 550 1,657 550 1,657 Cash, cash equivalents, and restricted cash $ 18,835 $ 47,039 $ 7,798 $ 6,404 Cash Equivalents All highly liquid investments purchased with an original maturity of three months or less are considered to be cash equivalents. Restricted Cash MGE has certain cash accounts that are restricted to uses other than current operations and designated for a specific purpose. MGE's restricted cash accounts include cash held by trustees for certain employee benefits and cash deposits held by third parties. These are included in "Other current assets" on the consolidated balance sheets. Receivable – Margin Account Cash amounts held by counterparties as margin collateral for certain financial transactions are recorded as Receivable – margin account in "Other current assets" on the consolidated balance sheets. The costs being hedged are fuel for electric generation, purchased power, and cost of gas sold. e. Trade Receivables, Allowance for Doubtful Accounts, and Concentration Risk - MGE Energy and MGE. Trade accounts receivable are recorded at the invoiced amount and do not bear interest. A 1 % late payment charge is recorded on all receivables unpaid after the due date. The allowance for credit losses associated with these receivables represents MGE's best estimate of the amount of probable credit losses for existing accounts receivable. MGE manages concentration of credit risk through its credit and collection policies, which are consistent with state regulatory requirements. The allowance for credit losses is estimated based on historical write-off experience, regional economic data, review of the accounts receivable aging, and reasonable and supportable forecasts that affect the collectability of the reported amount. MGE has considered the effects of COVID-19 developments in its estimate of allowance for credit losses. As of December 31, 2021 and 2020, MGE had a reserve balance of $ 8.3 million and $ 7.1 million, respectively, against accounts receivable. During the years ended December 31, 2021 and 2020, MGE recorded $ 2.2 million and $ 1.4 million, respectively, in write-offs. During the years ended December 31, 2021 and 2020, MGE recorded $ 3.4 million and $ 5.2 million, respectively, of additional reserves. The current accounting treatment for bad debt expense allows MGE to defer any differential between bad debt expense reflected in rates and actual costs incurred in its next rate case filing. See Footnote 8 for further details of deferred bad debt expense. f. Inventories - MGE Energy and MGE. Inventories consist of natural gas in storage, fuel for electric generation, materials and supplies, and renewable energy credits (RECs). MGE values natural gas in storage, fuel for electric generation, and materials and supplies using average cost. REC allowances are included in "Materials and supplies" on the consolidated balance sheets and are recorded based on specific identification. These allowances are charged to purchase power expense as they are used in operations. MGE's REC allowance balance as of December 31, 2021 and 2020, was $ 1.0 million and $ 0.8 million, respectively. g. D erivative and Hedging Instruments - MGE Energy and MGE. As part of regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices. MGE recognizes derivatives, excluding those that qualify for the normal purchases or normal sales exclusion, in the consolidated balance sheets at fair value, with changes in the fair value of derivative instruments to be recorded in current earnings or deferred in accumulated other comprehensive income (loss), depending on whether a derivative is designated as, and is effective as, a hedge and on the type of hedge transaction. Derivative activities are in accordance with the company's risk management policy. If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability depending on whether the derivative is in a net loss or net gain position, respectively. Cash flows from such derivative instruments are classified on a basis consistent with the nature of the underlying hedged item. h. Regulatory Assets and Liabilities - MGE Energy and MGE. Regulatory assets and regulatory liabilities are recorded consistent with regulatory treatment. Regulatory assets represent costs which are deferred due to the probable future recovery from customers through regulated rates. Regulatory liabilities represent the excess recovery of costs or accrued credits which were deferred because MGE believes it is probable such amounts will be returned to customers through future regulated rates. Regulatory assets and liabilities are amortized in the consolidated statements of income consistent with the recovery or refund included in customer rates. MGE believes it is probable that its recorded regulatory assets and liabilities will be recovered and refunded, respectively, in future rates. See Footnote 8 for further information. i. Debt Issuance Costs - MGE Energy and MGE. Premiums, discounts, and expenses incurred with the issuance of outstanding long-term debt are amortized over the life of the debt issue. Any call premiums or unamortized expenses associated with refinancing higher-cost debt obligations used to finance utility-regulated assets and operations are amortized consistent with regulatory treatment of those items. These costs are included as a direct reduction to the related debt liability on the consolidated balance sheets. j. Property, Plant, and Equipment - MGE Energy and MGE. Property, plant, and equipment is recorded at original cost. Cost includes indirect costs consisting of payroll taxes, pensions, postretirement benefits, other fringe benefits, and administrative and general costs. Also, included in the cost is AFUDC for utility property and capitalized interest for nonregulated property. Additions for significant replacements of property are charged to property, plant, and equipment at cost; and minor items are charged to maintenance expense. Depreciation rates on utility property are approved by the PSCW, based on the estimated economic lives of property, and include estimates for salvage value and removal costs. Removal costs of utility property, less any salvage value, are adjusted through regulatory liabilities. Depreciation rates on nonregulated property are based on the estimated economic lives of the property. See Footnote 4 for further information. Provisions at composite straight-line depreciation rates approximate the following percentages for the cost of depreciable property: 2021 2020 2019 Electric 3.2 % 3.5 % 3.6 % Gas 2.2 % 2.2 % 2.1 % Nonregulated 2.4 % 2.3 % 2.3 % k. Asset Retirement Obligations - MGE Energy and MGE. A liability is recorded for the fair value of an asset retirement obligation (ARO) to be recognized in the period in which it is incurred if it can be reasonably estimated. The offsetting associated asset retirement costs are capitalized as a long-lived asset and depreciated over the asset's useful life. The expected present value technique used to calculate the fair value of ARO liabilities includes assumptions about costs, probabilities, settlement dates, interest accretion, and inflation. Revisions to the assumptions, including the timing or amount of expected asset retirement costs, could result in increases or decreases to the AROs. All asset retirement obligations are recorded as "Other long-term liabilities" on the consolidated balance sheets. MGE has regulatory treatment and recognizes regulatory assets or liabilities for the timing differences between when it recovers legal AROs in rates and when it would recognize these costs. See Footnote 17 for further information. l. Repairs and Maintenance Expense - MGE Energy and MGE. MGE utilizes the direct expensing method for planned major maintenance projects. Under this method, MGE expenses all costs associated with major planned maintenance activities as incurred. m. Purchased Gas Adjustment Clause - MGE Energy and MGE. MGE's natural gas rates are subject to a fuel adjustment clause designed to recover or refund the difference between the actual cost of purchased gas and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates. As of December 31, 2021 and 2020, MGE had over collected $ 1.4 million and $ 1.8 million, respectively. These amounts are included in "Regulatory liabilities – current" on the consolidated balance sheets. n. Revenue Recognition - MGE Energy and MGE. Operating revenues are recorded as service is rendered or energy is delivered to customers. Meters are read on a systematic basis throughout the month based on established meter-reading schedules. At the end of the month, MGE accrues an estimate for the unbilled amount of energy delivered to customers. The unbilled revenue estimate is based on daily system demand volumes, weather factors, estimated line losses, estimated customer usage by class, and applicable customer rates. See Footnote 20 for further information. o. Utility Cost Recovery - MGE Energy and MGE. MGE's tariff rates include a provision for fuel cost recovery. The PSCW allows Wisconsin utilities to defer electric fuel-related costs, less excess revenues, that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its annual fuel proceedings. Any over- or under-recovery of the actual costs in a given year is determined in the following year and is then reflected in future billings to electric retail customers. Over-collection of fuel-related costs that are outside the approved range will be recognized as a reduction of revenue. Under-collection of these costs will be recognized in "Purchased power" expense in the consolidated statements of income. The cumulative effects of these deferred amounts will be recorded as a regulatory asset or regulatory liability until they are reflected in future billings to customers. See Footnote 9.b. for further information. p. Regional Transmission Organizations - MGE Energy and MGE. MGE reports on a net basis transactions on the MISO markets in which it buys and sells power within the same hour to meet electric energy delivery requirements. This treatment resulted in a $ 113.6 million, a $ 61.8 million, and a $ 75.6 million reduction to sales to the market and purchase power expense for MISO markets for the years ended December 31, 2021, 2020, and 2019 , respectively. q. Allowance for Funds Used During Construction - MGE Energy and MGE. Allowance for funds used during construction is included in utility plant accounts and represents the cost of borrowed funds used during plant construction and a return on shareholder's capital used for construction purposes. In the consolidated income statements, the cost of borrowed funds (AFUDC-debt) is presented as an offset to "Interest expense" and the return on shareholder's capital (AFUDC-equity funds) is shown as an item within "Other income." For 2021, 2020 and 2019 , as approved by the PSCW, MGE capitalized AFUDC-debt and equity on 50 % of applicable average construction work in progress at 6.89 %, 7.03 %, and 7.00 %, respectively. MGE received specific approval to recover 100 % AFUDC on certain costs for Saratoga, Two Creeks, Badger Hollow I and II, its customer information and billing project, and on certain environmental costs for Columbia. These amounts are recovered under the ratemaking process over the service lives of the related properties. During 2021, 2020, and 2019, MGE recorded $ 1.7 million, $ 2.1 million, and $ 0.8 million, respectively, of AFUDC-debt. During 2021, 2020, and 2019, MGE recorded $ 5.0 million, $ 5.9 million, and $ 2.3 million, respectively, of AFUDC-equity. r. Investments - MGE Energy and MGE. Investments in limited liability companies that have specific ownership accounts in which MGE Energy or MGE's ownership interest is more than minor and are considered to have significant influence are accounted for using the equity method. For equity security investments without readily determinable fair values and for which MGE Energy and MGE do not have significant influence, MGE Energy and MGE have elected to use the practicability exception to measure these investments, defined as cost adjusted for changes from observable transactions for identical or similar investments of the same issuer, less impairment. Changes in measurement are reported in earnings. Equity security investments with readily determinable fair values are carried at fair value. Realized and unrealized gains and losses are included in earnings. See Footnote 7 for further information on investments and Footnote 19 for further information on fair value of investments. s. Capitalized Software Costs - MGE Energy and MGE. The net book value of capitalized costs of internal use software included in property, plant, and equipment was $ 85.8 million and $ 20.4 million as of December 31, 2021 and 2020, respectively. MGE implemented a new customer information system which went live in September 2021. As of December 31, 2021 and 2020, accumulated amortization was $ 42.6 million and $ 36.9 million, respectively. During 2021, MGE recorded $ 5.7 million of amortization expense. During 2020 and 2019, MGE recorded $ 5.1 million of amortization expense. Capitalized software costs are amortized on a straight-line basis over the estimated useful lives of the assets. The useful lives range from five to fifteen years. t. Capitalized Software Assets – Hosting Arrangements – MGE Energy and MGE. The net book value of capitalized costs of internal use software incurred in a hosting arrangement was $ 15.6 million and $ 14.8 million as of December 31, 2021 and 2020, respectively. As of December 31, 2021 and 2020, accumulated amortization was $ 5.4 million and $ 3.2 million, respectively. Capitalized software assets for hosted arrangements and the related accumulated amortization expense are recorded in "Other deferred assets and other" on the consolidated balance sheets. During 2021, 2020, and 2019, MGE recorded $ 2.2 million, $ 1.8 million, and $ 1.4 million, respectively, of amortization expense related to software assets for hosted arrangements. These costs are recognized in "Other operations and maintenance" expense in the consolidated statements of income and are amortized on a straight-line basis over the term of the hosted contract, which includes renewable option periods. Software assets for hosted arrangements have terms ranging from three to ten years. u. Impairment of Long-Lived Assets - MGE Energy and MGE. MGE reviews plant and equipment and other property for impairment when events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. MGE's policy for determining when long-lived assets are impaired is to recognize an impairment loss if the sum of the expected future cash flows (undiscounted and without interest charges) from an asset are less than the carrying amount of that asset. If an impairment loss is recognized, the amount that will be recorded will be measured as the amount by which the carrying amount of the asset exceeds the fair value of the asset. When it becomes probable that a generating unit will be retired before the end of its useful life, MGE assesses whether the generating unit meets the criteria for probability of abandonment. If a generating unit meets the applicable criteria to be considered probable of abandonment, MGE assesses the likelihood of recovery of the remaining net book value of that generating unit at the end of each reporting period. If it becomes probable that regulators will disallow full recovery or a return on the remaining net book value of a generating unit that is either abandoned or probable of being abandoned, an impairment loss would be required. An impairment loss would be recorded for the difference of the remaining net book value of the generating unit that is greater than the present value of the amount expected to be recovered from ratepayers. There was no impairment of long-lived assets during 2021, 2020, and 2019 . v. Income Taxes and Excise Taxes - MGE Energy and MGE. Income taxes Under the liability method, income taxes are deferred for all temporary differences between pretax financial and taxable income and between the book and tax basis of assets and liabilities using the tax rates scheduled by law to be in effect when the temporary differences reverse. Future tax benefits are recognized to the extent that realization of such benefits is more likely than not. A valuation allowance is recorded for those benefits that do not meet this criterion. Accounting for uncertainty in income taxes applies to all tax positions and requires a recognition threshold and measurement standard for the financial statement recognition and measurement of a tax position taken, or expected to be taken, in an income tax return. The threshold is defined for recognizing tax return positions in the financial statements as "more likely than not" that the position is sustainable, based on its merits. Subsequent recognition, derecognition, and measurement is based on management's best judgment given the facts, circumstances, and information available at the reporting date. Regulatory and accounting principles have resulted in a regulatory liability related to income taxes. Excess deferred income taxes result from past taxes provided in customer rates higher than current rates. The income tax regulatory liability and deferred investment tax credit reflect the revenue requirement associated with the return of these tax benefits to customers. Investment tax credits from regulated operations are amortized over related property service lives. Excise taxes MGE Energy, through its utility operations, pays a state license fee tax in lieu of property taxes on property used in utility operations. License fee tax is calculated as a percentage of adjusted operating revenues of the prior year. The electric tax rate is 3.19 % for retail sales and 1.59 % for sales of electricity for resale by the purchaser. The tax rate on sales of natural gas is 0.97 %. The tax is required to be estimated and prepaid in the year prior to its computation and expensing. License fee tax expense, included in "Other general taxes," was $ 13.5 million, $ 14.1 million, and $ 13.9 million for the years ended December 31, 2021, 2020, and 2019, respectively. Operating income taxes, including tax credits and license fee tax, are included in rates for utility related items. w. Share-Based Compensation - MGE Energy and MGE. Eligible employees and non-employee directors may receive awards of restricted stock, restricted stock units, performance units, and dividend equivalents, or any combination of the foregoing. Stock-based compensation expense is recognized on a straight-line basis over the requisite service period. Awards classified as equity awards are measured based on their grant-date fair value. Awards classified as liability awards are recorded at fair value each reporting period. Forfeitures are recognized as they occur, rather than estimating potential future forfeitures and recording them over the vesting period. See Footnote 12 for additional information on MGE's share-based compensation plans. |
New Accounting Standards
New Accounting Standards | 12 Months Ended |
Dec. 31, 2021 | |
New Accounting Pronouncements and Changes in Accounting Principles [Abstract] | |
New Accounting Pronouncements | 2. New Acco unting Standards - MGE Energy and MGE. MGE Energy and MGE reviewed FASB authoritative guidance recently issued, none of which are expected to have a material impact on the consolidated results of operations, financial condition, or cash flows. |
Variable Interest Entities
Variable Interest Entities | 12 Months Ended |
Dec. 31, 2021 | |
Variable Interest Entities Disclosure [Abstract] | |
Variable Interest Entities | 3. Variable Inte rest Entities - MGE Energy and MGE. a. Consolidated Variable Interest Entities. MGE Power Elm Road and MGE Power West Campus are not subsidiaries of MGE, but they have been consolidated in the financial statements of MGE. MGE Power Elm Road and MGE Power West Campus were created for the purpose of owning new generating assets and leasing those assets to MGE. MGE Power Elm Road's sole principal asset is an undivided ownership interest in two coal-fired generating plants (the Elm Road Units) located in Oak Creek, Wisconsin, which it leases to MGE pursuant to long-term leases. MGE Power West Campus's sole principal asset is the WCCF, which it leases to MGE pursuant to a long-term lease. Based on the nature and terms of the contractual agreements, MGE is expected to absorb a majority of the expected losses or residual value associated with the ownership of the generation assets by MGE Power Elm Road and MGE Power West Campus and therefore MGE holds a variable interest despite the absence of an equity interest. In accordance with applicable accounting guidance, MGE Energy and MGE consolidate VIEs of which they are the primary beneficiary. MGE has the power to direct the activities that most significantly impact both the Elm Road Units' and the WCCF's economic performance and is also the party most closely associated with MGE Power Elm Road and MGE Power West Campus. As a result, MGE is the primary beneficiary. MGE has included the following significant accounts on its consolidated balance sheets related to its interest in these VIEs as of December 31: MGE Power Elm Road MGE Power West Campus (In thousands) 2021 2020 2021 2020 Property, plant, and equipment, net $ 163,325 $ 166,883 $ 79,183 $ 79,077 Construction work in progress 898 697 493 677 Affiliate receivables — — 2,211 2,803 Accrued interest and accrued (prepaid) taxes 37 2,701 ( 75 ) 671 Deferred income taxes 30,696 30,646 14,726 14,521 Long-term debt (a) 48,968 51,590 35,563 37,652 Noncontrolling interest 101,507 96,856 47,080 44,340 (a) MGE Power Elm Road's long-term debt includes debt issuance costs of $ 0.3 million and $ 0.4 million as of December 31, 2021 and 2020, respectively. The debt is secured by a collateral assignment of lease payments that MGE makes to MGE Power Elm Road for use of the Elm Road Units pursuant to the related long-term leases. MGE Power West Campus's long-term debt includes debt issuance costs of $ 0.1 million as of December 31, 2021 and 2020 . The debt is secured by a collateral assignment of lease payments that MGE makes to MGE Power West Campus for use of the cogeneration facility pursuant to the long-term lease. See Footnote 14 for further information on the long-term debt securities . MGE is permitted by PSCW order to recover lease payments made to MGE Power Elm Road and MGE Power West Campus in customer rates. b. Other Variable Interest Entities. MGE has a variable interest in entities through purchase power agreements relating to purchased energy from the facilities covered by the agreements. As of December 31, 2021 and 2020 , MGE had 13 megawatts of capacity available under these agreements. MGE evaluated the variable interest entities for possible consolidation. The interest holder is considered the primary beneficiary of the entity and is required to consolidate the entity if the interest holder has the power to direct the activities that most significantly impact the economics of the variable interest entity. MGE examined qualitative factors such as the length of the remaining term of the contracts compared with the remaining lives of the plants, who has the power to direct the operations and maintenance of the facilities, and other factors, and determined MGE is not the primary beneficiary of the variable interest entities. There is no significant potential exposure to loss as a result of involvement with these variable interest entities. |
Property, Plant, and Equipment
Property, Plant, and Equipment | 12 Months Ended |
Dec. 31, 2021 | |
Property, Plant and Equipment [Abstract] | |
Property, Plant and Equipment | 4. Property, Plant, and Equipment - MGE Energy and MGE. Property, plant, and equipment consisted of the following as of December 31: MGE Energy MGE (In thousands) 2021 2020 2021 2020 Utility: Electric (a)(b) $ 1,516,533 $ 1,608,658 $ 1,516,550 $ 1,608,675 Plant anticipated to be retired early (a) 158,983 — 158,983 — Gas 546,390 496,450 546,401 496,461 Utility property, plant, and equipment, gross 2,221,906 2,105,108 2,221,934 2,105,136 Less: Accumulated depreciation and amortization (a) 636,804 721,382 636,804 721,382 Utility property, plant, and equipment, net 1,585,102 1,383,726 1,585,130 1,383,754 Nonregulated: Nonregulated 317,881 320,691 317,881 320,691 Less: Accumulated depreciation and amortization 74,812 74,131 74,812 74,131 Nonregulated property, plant, and equipment, net 243,069 246,560 243,069 246,560 Construction work in progress: Utility construction work in progress (b) 49,211 137,725 49,211 137,725 Nonregulated construction work in progress 1,392 1,374 1,392 1,374 Total property, plant, and equipment $ 1,878,774 $ 1,769,385 $ 1,878,802 $ 1,769,413 (a) An asset that will be retired in the near future and substantially in advance of its previously expected retirement date is subject to abandonment accounting. In the second quarter of 2021, the operator of Columbia received approval from MISO to retire Columbia Units 1 and 2. The co-owners intend to retire Unit 1 by the end of 2023 and Unit 2 by the end of 2024. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. As of December 31, 2021, early retirement of Columbia was probable. "Plant anticipated to be retired early" in table above is the net book value of these generating units. Assets for Columbia Unit 1 and Unit 2 are currently included in rate base, and MGE continues to depreciate them on a straight-line basis using the composite depreciation rates approved by the PSCW that included retirement dates of 2029 for Unit 1 and 2038 for Unit 2. If it becomes probable that regulators will disallow full recovery or a return on the remaining net book value of a generating unit that is either abandoned or probable of being abandoned, an impairment loss would be required. An impairment loss would be recorded for the difference of the remaining net book value of the generating unit that is greater than the present value of the amount expected to be recovered from ratepayers. No impairment was recorded as of December 31, 2021. (b) Three major projects were placed in service in 2021. Electric only utility projects were O'Brien Solar Fields completed in May and Badger Hollow I completed in November. Implementation of a new Customer Information System, an electric and gas utility project, went live in September . MGE's utility plant is subject to the lien of its Indenture of Mortgage and Deed of Trust. As of December 31, 2021 and 2020, there was $ 1.2 million of first mortgage bonds outstanding under that indenture. See Footnote 14 for further discussion of the mortgage indenture and the entitlement of certain unsecured notes to be equally and ratably secured if MGE issues additional first mortgage bonds |
Leases
Leases | 12 Months Ended |
Dec. 31, 2021 | |
Leases [Abstract] | |
Lease | 5. Leas es - MGE Energy and MGE. As part of its regular operations, MGE enters into various contracts related to IT equipment, substations, cell towers, land, wind easements, and other property in use for operations. A contract is or contains a lease if the contract conveys the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. Determination as to whether an arrangement is or contains a lease is completed at inception. Leases with an initial term of 12 months or less are not recorded on the consolidated balance sheets; lease expense for these leases are recognized on a straight-line basis over the lease term. Leases with initial terms in excess of 12 months are recorded as operating or financing leases on the consolidated balance sheets. Operating lease assets and operating lease liabilities are recognized based on the present value of the future minimum lease payments over the lease term at commencement date. For leases that do not provide an implicit rate, a collateralized incremental borrowing rate based on the information available at commencement date, including lease term, is used in determining the present value of future payments. The operating lease asset also includes any lease payments made and excludes lease incentives and initial direct costs incurred. Lease terms may include options to extend or terminate the lease when it is reasonably certain that the option will be exercised. Operating lease expense is recognized on a straight-line basis over the lease term. MGE has regulatory treatment and recognizes regulatory assets or liabilities for timing differences between when net lease costs are recorded and when costs are recognized. As of December 31, 2021 , MGE had no significant leases not yet commenced that would create significant future rights and obligations. The following table shows lease expense for the years ended December 31: (In thousands) 2021 2020 Income Statement Location Finance lease expense: Amortization of leased assets $ 1,609 $ 1,694 Depreciation and amortization Interest on lease liabilities 771 784 Interest expense, net Operating lease expense 506 319 Other operations and maintenance Total lease expense $ 2,886 $ 2,797 The following table shows the lease assets and liabilities on the consolidated balance sheets as of December 31: (In thousands) 2021 2020 Balance Sheet Location Lease assets: Finance lease assets $ 15,545 $ 15,682 Property, plant, and equipment, net Operating lease assets 7,961 5,988 Other deferred assets and other Total lease assets $ 23,506 $ 21,670 Lease liabilities: Finance lease liabilities - current $ 1,050 $ 1,066 Other current liabilities Finance lease liabilities - long-term 17,322 17,532 Finance lease liabilities Operating lease liabilities - current 161 171 Other current liabilities Operating lease liabilities - long-term 7,965 5,840 Other deferred liabilities and other Total lease liabilities $ 26,498 $ 24,609 The following table shows other lease information for the years ended December 31: (In thousands) 2021 2020 Cash paid for amounts included in the measurement of lease liabilities: Finance leases - Financing cash flows $ 1,495 $ 1,149 Finance leases - Operating cash flows 771 784 Operating leases - Operating cash flows 362 319 Lease assets obtained in exchange for lease liabilities: Finance leases 1,026 1,480 Operating leases 2,178 5,791 The following table shows the weighted average remaining lease terms and discounts as of December 31: Weighted-average remaining lease terms (in years): 2021 2020 Finance leases 38 37 Operating leases 35 34 Weighted-average discount rates: Finance leases 4.30 % 4.32 % Operating leases 3.07 % 2.84 % The following table shows maturities of lease liabilities as of December 31: (In thousands) Finance Operating 2022 $ 1,787 $ 399 2023 1,616 329 2024 1,163 304 2025 965 294 2026 845 299 Thereafter 39,726 12,133 Subtotal 46,102 13,758 Less: Present value discount ( 27,730 ) ( 5,632 ) Lease liability 18,372 8,126 Less: current portion ( 1,050 ) ( 161 ) Noncurrent lease liability $ 17,322 $ 7,965 |
Joint Plant Ownership
Joint Plant Ownership | 12 Months Ended |
Dec. 31, 2021 | |
Regulated Operations [Abstract] | |
Joint Plant Ownership | 6. Joint Plant Ownership - MGE Energy and MGE. MGE has undivided ownership interests in jointly owned facilities. Generation and operating expenses are primarily divided between the joint owners under the same method as ownership. MGE provides its own financing and the respective portion of facilities and costs are included in the corresponding operating expenses (fuel for electric generation, purchased power, other operations and maintenance, etc.) in the consolidated statements of income. The following table shows MGE's interest in utility plant in service, and the related accumulated depreciation reserves and other information related to MGE's jointly owned facilities: (In thousands, except for Columbia (a) Elm Road (b) West Campus (c) Forward Wind (d) Two Creeks (e) Badger Hollow (f) Ownership interest 19 % 8.33 % 55 % 12.8 % 33 % 33 % Share of generation (MW) 211 MW 106 MW 157 MW 18 MW 50 MW 100 MW For the year ended December 31, Operating expense - 2021 $ 33,284 $ 18,478 $ (g) $ 669 $ 953 $ 140 Operating expense - 2020 27,127 17,259 (g) 664 118 — Operating expense - 2019 32,604 19,661 (g) 642 — — As of December 31, 2021 Utility plant $ — $ 202,604 $ 114,090 $ 34,084 $ 67,814 $ 69,178 Accumulated depreciation — ( 39,279 ) ( 34,907 ) ( 14,945 ) ( 2,932 ) ( 227 ) Plant anticipated to be 158,983 — — — — — Construction work in progress 2,388 898 493 21 — 19,748 As of December 31, 2020 Utility plant $ 289,597 $ 203,847 $ 115,657 $ 34,028 $ 67,577 $ — Accumulated depreciation ( 118,742 ) ( 36,964 ) ( 36,580 ) ( 14,092 ) ( 225 ) — Construction work in progress 997 697 677 — — 63,140 (a) In February 2021, MGE and the other co-owners announced plans to retire Columbia, a two unit coal-fired generation facility located in Portage, Wisconsin. The co-owners intend to retire Unit 1 by the end of 2023 and Unit 2 by the end of 2024. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. As of December 31, 2021, early retirement of Columbia was probable. See Footnote 4 for further information. (b) Two coal-fired generating units in Oak Creek, Wisconsin. In November 2021, MGE announced plans to end the use of coal as a primary fuel at the Elm Road Units and transition the plant to natural gas. (c) MGE Power West Campus and the UW jointly own the West Campus Cogeneration Facility (WCCF) located on the UW campus in Madison, Wisconsin. The UW owns a controlling interest in the chilled-water and steam plants, which are used to meet the needs for air-conditioning and steam-heat capacity for the UW campus. MGE Power West Campus owns a controlling interest in the electric generation plant, which is leased and operated by MGE. (d) The Forward Wind Energy Center (Forward Wind) consists of 86 wind turbines located near Brownsville, Wisconsin. (e) The Two Creeks solar generation array is located in the Town of Two Creeks and the City of Two Rivers in Manitowoc and Kewaunee Counties, Wisconsin. Date of commercial operation of the solar array was November 2020. (f) The Badger Hollow I and II solar farm is located in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb. Badger Hollow I and II. Date of commercial operation of Badger Hollow I was November 2021. Construction of Badger Hollow II is expected to be completed in March 2023. (g) Operating charges are allocated to the UW based on formulas contained in the operating agreement. Under the provisions of this arrangement, the UW is required to reimburse MGE for their allocated portion of fuel and operating expenses. For the years ended December 31, 2021, 2020, and 2019, the UW's allocated share of fuel and operating costs was $ 6.2 million, $ 5.2 million, and $ 6.6 million, respectively. |
Investments
Investments | 12 Months Ended |
Dec. 31, 2021 | |
Investments Disclosure [Abstract] | |
Investments | 7. Investme nts - MGE Energy and MGE. a. Equity Securities, Equity Method Investments, and Other Investments. MGE Energy MGE (In thousands) 2021 2020 2021 2020 Equity securities $ 20,529 $ 17,906 $ 230 $ 603 Equity method investments: ATC and ATC Holdco 75,862 74,423 — — Other 39 39 — — Total equity method investments 75,901 74,462 — — Other investments 2,324 2,308 — — Total $ 98,754 $ 94,676 $ 230 $ 603 Equity securities represent publicly traded securities and private equity investments in common stock of companies in various industries. During the years ended December 31, 2021, 2020, and 2019, certain investments were liquidated. As a result of these liquidations, the following was received: MGE Energy MGE (In thousands) 2021 2020 2019 2021 2020 2019 Cash proceeds $ 1,684 $ 622 $ 216 $ — $ — $ 2 Gain (loss) on sale 1,543 379 580 — — ( 343 ) b. ATC and ATC Holdco. ATC owns and operates electric transmission facilities primarily in Wisconsin. MGE received an interest in ATC when it, like other Wisconsin electric utilities, contributed its electric transmission facilities to ATC as required by Wisconsin law. That interest is presently held by MGE Transco, a subsidiary of MGE Energy. ATC Holdco was formed by several members of ATC, including MGE Energy, to pursue electric transmission development and investments outside of Wisconsin. The ownership interest in ATC Holdco is held by MGEE Transco, a subsidiary of MGE Energy. As of December 31, 2021 and 2020, MGE Transco held a 3.6 % ownership interest in ATC. As of December 31, 2021 and 2020, MGEE Transco held a 4.4 % ownership interest in ATC Holdco. MGE Transco and MGEE Transco have accounted for their investment in ATC and ATC Holdco, respectively, under the equity method of accounting. Equity earnings from investments are recorded as "Other income" on the consolidated statements of income of MGE Energy. For the years ended December 31, MGE Transco recorded the following: (In thousands) 2021 2020 2019 Equity earnings from investment in ATC $ 9,774 $ 10,167 $ 9,889 Dividends received from ATC 7,832 8,633 7,347 Capital contributions to ATC — 1,249 3,018 In January 2022, MGE Transco made a $ 1.2 million capital contribution to ATC. ATC Holdco was formed in December 2016. ATC Holdco's transmission development activities have been suspended for the near term. In 2020 and 2019, MGEE Transco recorded capital contributions of $ 0.3 million and $ 0.1 million, respectively, to ATC Holdco. In 2021 , MGEE Transco recorded no capital contributions to ATC Holdco. ATC's summarized financial data is as follows: (In thousands) Income statement data for the year ended December 31, 2021 2020 2019 Operating revenues $ 754,838 $ 758,117 $ 744,371 Operating expenses ( 376,153 ) ( 372,463 ) ( 373,527 ) Other income 1,144 1,922 48 Interest expense, net ( 115,089 ) ( 112,818 ) ( 110,490 ) Earnings before members' income taxes $ 264,740 $ 274,758 $ 260,402 Balance sheet data as of December 31, 2021 2020 Current assets $ 89,747 $ 92,735 Noncurrent assets 5,628,127 5,400,538 Total assets $ 5,717,874 $ 5,493,273 Current liabilities $ 436,918 $ 310,749 Long-term debt 2,513,009 2,512,246 Other noncurrent liabilities 421,997 378,205 Members' equity 2,345,950 2,292,073 Total members' equity and liabilities $ 5,717,874 $ 5,493,273 MGE receives transmission and other related services from ATC. During 2021, 2020, and 2019, MGE recorded $ 32.0 million, $ 30.7 million, and $ 30.4 million, respectively, for transmission services received from ATC. MGE also provides a variety of operational, maintenance, and project management work for ATC, which is reimbursed by ATC. As of December 31, 2021 and 2020, MGE had a receivable due from ATC of $ 7.0 million and $ 2.6 million, respectively, related primarily to transmission interconnection at Badger Hollow I and II. MGE is reimbursed for these costs after the new generation assets are placed into service. |
Regulatory Assets and Liabiliti
Regulatory Assets and Liabilities | 12 Months Ended |
Dec. 31, 2021 | |
Regulatory Assets and Liabilities Disclosure [Abstract] | |
Regulatory Assets and Liabilities | 8. Regulator y Assets and Liabilities - MGE Energy and MGE. The following regulatory assets and liabilities are reflected in MGE's consolidated balance sheets as of December 31: (In thousands) 2021 2020 Regulatory Assets Asset retirement obligation $ 13,081 $ 11,935 Deferred fuel costs 3,292 — Deferred bad debt expense 5,600 3,750 Debt related costs 8,173 8,586 Deferred pension and other postretirement costs 1,017 5,280 Derivatives — 13,989 Leases 2,992 2,748 Tax recovery related to AFUDC equity 10,347 8,952 Unfunded pension and other postretirement liability 63,728 101,594 Other 782 418 Total Regulatory Assets $ 109,012 $ 157,252 Regulatory Liabilities Deferred fuel savings $ — $ 5,047 Derivatives 617 — Elm Road — 1,957 Income taxes 110,817 129,856 Non-ARO removal costs 29,694 28,197 Pension and other postretirement service costs 11,451 7,524 Deferred pension and other postretirement costs 8,112 — Purchased gas adjustment 1,448 1,832 Renewable energy credits 1,001 802 Transmission 223 7,669 Other 300 1,019 Total Regulatory Liabilities $ 163,663 $ 183,903 MGE expects to recover its regulatory assets and return its regulatory liabilities through rates charged to customers based on PSCW decisions made during the ratemaking process or based on PSCW long-standing policies and guidelines. The adjustments to rates for these regulatory assets and liabilities will occur over the periods either specified by the PSCW or over the corresponding period related to the asset or liability. Management believes it is probable that MGE will continue to recover from customers the regulatory assets described above based on prior and current ratemaking treatment for such costs. Asset Retirement Obligation See Footnote 17 for a discussion of asset retirement obligations. Deferred Fuel Costs/Savings The fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band. Any over- or under-recovery of the actual costs is determined on an annual basis and is adjusted in future billings to electric retail customers. See Footnote 9.b. for further discussion. Deferred bad debt expense In March 2020, the PSCW issued an order authorizing deferral of expenditures incurred to ensure the provision of safe, reliable, and affordable access to utility services during the COVID-19 pandemic and late payment charges. Expenditures include items such as bad debt expense. Recovery of expenditures is expected to be addressed in future rate proceedings. While management believes that cost recovery is probable, the timing of collection from customers cannot be estimated at this time. Management will continue to assess the probability of recovery of deferred costs. As part of the 2021 settlement agreement, the PSCW approved MGE to defer any differential between bad debt expense reflected in rates and actual costs incurred in its next rate filing. Debt Related Costs This balance includes debt issuance costs of extinguished debt and other debt related expenses, including make-whole premiums paid on redemptions of long-term debt. The PSCW has allowed rate recovery on unamortized issuance costs for extinguished debt facilities. When the facility replacing the old facility is deemed by the PSCW to be more favorable for the ratepayers, the PSCW will allow rate recovery of any unamortized issuance costs related to the old facility. These amounts are recovered over the term of the new facility. Deferred Pension and Other Postretirement Costs The current accounting treatment for Pension and Other Postretirement costs allows MGE to reflect any differential between pension and other postretirement costs reflected in rates and actual costs incurred in its next rate filing. Derivatives MGE has physical and financial contracts that are accounted for as derivatives. The amounts recorded for the net mark-to-market value of the commodity based contracts is offset with a corresponding regulatory asset or liability because these transactions are part of the PGA or fuel rules clause authorized by the PSCW. A significant portion of the recorded amount is related to a purchased power agreement that provides MGE with firm capacity and energy during a base term that began on June 1, 2012, and ends on May 31, 2022. See Footnote 18 for further discussion. Leases As part of its regular operations, MGE enters into various contracts related to IT equipment, substations, cell towers, land, wind easements, and other property in use for operations. Leases with initial terms in excess of 12 months are recorded as operating or financing leases on the consolidated balance sheets. MGE has regulatory treatment and recognizes regulatory assets or liabilities for timing differences between when net lease costs are recorded and when costs are recognized. See Footnote 5 for further information. Tax Recovery Related to AFUDC Equity AFUDC equity represents the after-tax equity cost associated with utility plant construction and results in a temporary difference between the book and tax basis of such plant. It is probable under PSCW regulation that MGE will recover in future rates the future increase in taxes payable represented by the deferred income tax liability. The amounts will be recovered in rates over the depreciable life of the asset for which AFUDC was applied. Tax recovery related to AFUDC equity represents the revenue requirement related to recovery of these future taxes payable, calculated at current statutory tax rates. Unfunded Pension and Other Postretirement Liability MGE is required to recognize the unfunded or funded status of defined benefit pension and other postretirement pension plans as a net liability or asset on the balance sheet with an offset to a regulatory asset or liability. The unfunded status represents future expenses that are expected to be recovered in rates. See Footnote 11 for further discussion. Elm Road Costs associated with Elm Road are estimated in MGE's rates and include costs for lease payments, management fees, community impact mitigation, and operating costs. Costs are collected in rates over a one to two-year period. The current accounting treatment for these costs allows MGE to reflect any differential between costs reflected in rates and actual costs incurred in its next rate filing. Income Taxes Excess deferred income taxes result from a decrease in tax rates subsequent to ratemaking settlements. The settlements were reached using tax rates that are higher than the currently applicable rates, and MGE is required to return these tax benefits to customers. The regulatory liability and deferred investment tax credit reflects the revenue requirement associated with the return of these tax benefits to customers. Changes in income taxes are generally passed through in customer rates for the regulated utility. The one-time 2017 impact on timing differences related to income taxes passed through to customer rates of the 2017 Tax Act was recorded as a regulatory liability. The amount and timing of the cash impacts will depend on the period over which certain income tax benefits are provided to customers, which will be subject to review by the PSCW. A portion of the regulatory liability will be returned to customers based on a mandated timeframe dictated by applicable tax laws. The 2021 rate settlement includes a one-time $ 18.2 million return to customers of the portion of electric excess deferred taxes related to the 2017 Tax Act not governed by IRS normalization rules. Non-ARO Removal Costs In connection with accounting for asset retirement obligations, companies are required to reclassify cumulative collections for non-ARO removal costs as a regulatory liability, with an offsetting entry to accumulated depreciation. Under the current rate structure, these removal costs are being recovered as a component of depreciation expense. Pension and Other Postretirement Service Costs The FASB issued authoritative guidance within the codification's Compensation-Retirement Benefits topic that only allows the service cost component of net periodic benefit cost to be eligible for capitalization within the consolidated balance sheets. Under the current rate structure, non-service cost components of net periodic benefit cost are being recovered as a component of depreciation expense. MGE has regulatory treatment and recognizes regulatory assets or liabilities for timing differences between when net periodic benefit costs are recovered and when costs are recognized. See Footnote 11 for further discussion. Purchased Gas Adjustment MGE's natural gas rates are subject to a fuel adjustment clause designed to recover or refund the difference between the actual cost of purchased gas and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates. Renewable Energy Credits MGE receives renewable energy credits from certain purchase power agreements. The value of the credits is recorded as inventory and expensed when the credit is redeemed or expired. A regulatory liability has been established for the value of the renewable energy credits included in inventory. In Wisconsin, renewable energy credits expire four years after the year of acquisition. Transmission Costs The current accounting treatment for transmission costs allows MGE to reflect any differential between transmission costs reflected in rates and actual costs incurred in its next rate filing. |
Rate Matters
Rate Matters | 12 Months Ended |
Dec. 31, 2021 | |
Regulated Operations [Abstract] | |
Rate Matters | 9. Rate Mat ters - MGE Energy and MGE. a. Rate Proceedings. In December 2021, the PSCW approved a settlement agreement for MGE's 2022 rate case. The settlement agreement provides for an 8.81 % increase for electric rates and a 2.15 % increase for gas rates in 2022. The electric and gas rate increases are driven by an increase in rate base including our investments in Badger Hollow I and a new customer information system. Also driving the requested electric increase are higher fuel and purchase power costs as well as the completion in 2021 of the one-time return of the electric excess deferred tax credit related to the 2017 Tax Act not restricted by IRS normalization rules. Included in the electric residential rate is a reduction in the customer charge. As part of the settlement agreement, for 2023, the PSCW approved a 0.96 % increase in gas rates and to address a potential electric rate change through a limited rate case re-opener. The return on common stock equity for 2022 and 2023 is 9.8 % based on a capital structure consisting of 55.6 % common equity. In December 2020, the PSCW approved a settlement agreement for MGE's 2021 rate case. The settlement agreement provided for a zero percent increase for electric rates and an approximately 4 % increase for gas rates in 2021. The electric rate settlement included an increase in rate base but the associated rate increase was primarily offset by lower fuel and purchase power costs and a one-time $ 18.2 million return to customers of the portion of excess deferred taxes related to the 2017 Tax Act not restricted by IRS normalization rules. As part of the settlement, the fuel rules bandwidth was set at plus or minus 1 % for 2021. When compared to the 2020 rate case, the settlement included lower forecasted electric sales for 2021 to reflect changes to customer usage during the COVID-19 pandemic. The gas rate increase covered infrastructure costs and technology improvements. The settlement agreement also included escrow accounting treatment for pension and other postretirement benefit costs, bad debt expense, and customer credit card fees. Escrow accounting treatment allows MGE to defer any difference between estimated costs in rates and actual costs incurred until its next rate filing. Any difference would be recorded as a regulatory asset or regulatory liability. The return on common stock equity for 2021 was 9.8 % based on a capital structure of 55.8 % common equity in 2021. Sierra Club and Vote Solar have filed petitions with the Dane County Circuit Court seeking review of the PSCW decision approving MGE's two most recent rate settlements (2021 and 2022/2023). The PSCW is named as the responding party; MGE is not named as a party. The petitions challenge the process the PSCW used to approve the portion of the settlements relating to electric rates and the electric customer fixed charge that does not vary with usage. The requested relief is unclear. The revenue requirement approved by the PSCW in the settlements have not been challenged. The PSCW is expected to vigorously defend its approval of the rate case settlements. MGE has intervened in the proceedings to further defend the PSCW's decision. In December 2018, the PSCW approved a settlement agreement between MGE and intervening parties in the then pending rate case. The settlement decreased electric rates by 2.24 % , or $ 9.2 million, in 2019. The decrease in electric rates reflected the ongoing impacts of the 2017 Tax Act. Lower fuel costs and an increase in rate base from renewable generation assets further impacted the rate change. In 2020, electric rates decreased a further 0.84 % , or $ 3.4 million, as approved by the PSCW in December 2019 in MGE's 2020 Fuel Cost Plan, which reflected lower fuel costs. The settlement agreement increased gas rates by 1.06 % , or $ 1.7 million, in 2019 and 1.46 % , or $ 2.4 million, in 2020. The gas increase covered infrastructure costs. It also reflected the impacts of the 2017 Tax Act. The return on common stock equity for 2019 and 2020 was 9.8 % based on a capital structure consisting of 56.6 % common equity in 2019 and 56.1 % common equity in 2020. b. Fuel Rules. Fuel rules require Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its annual fuel proceedings. Any over- or under-recovery of the actual costs is determined in the following year and is then reflected in future billings to electric retail customers. The fuel rules bandwidth is set at plus or minus 1 % in 2021. Under fuel rules, MGE defers costs, less any excess revenues, if its actual electric fuel costs exceed 101 % of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 99 % of the electric fuel costs allowed in that order. In 2020, the fuel rules bandwidth was set at plus or minus 2 % . These costs are subject to the PSCW's annual review of fuel costs completed in the year following the deferral. The PSCW issued a final decision in the 2019 fuel rules proceedings regarding $ 1.5 million of deferred savings giving MGE the option either to use the $ 1.5 million as part of the settlement to MGE's 2021 rate case or to refund the balance to customers in October 2020. MGE elected to include the savings as part of the 2021 rate change settlement as described above, reducing electric retail rates as opposed to a one-time credit back to retail customers. There was no change to the refund in the fuel rules proceedings from the amount MGE deferred in the previous year. In September 2021, the PSCW issued a final decision in the 2020 fuel rules proceedings for MGE to refund $ 3.2 million of additional fuel savings realized during 2020 plus accrued interest to its retail electric customers over a one-month period in October 2021. There was no change to the refund in the fuel rules proceedings from the amount MGE deferred in the previous year. MGE has under recovered fuel costs in 2021. As of December 31, 2021, MGE had deferred $ 3.3 million of 2021 fuel costs. These costs will be subject to the PSCW's annual review of 2021 fuel costs, expected to be completed in 2022. |
Income Taxes
Income Taxes | 12 Months Ended |
Dec. 31, 2021 | |
Income Tax Disclosure [Abstract] | |
Income Taxes | 10. Income Ta xes. a. MGE Energy and MGE Income Taxes. MGE Energy files a consolidated federal income tax return that includes the operations of all subsidiary companies. The subsidiaries calculate their respective federal income tax provisions as if they were separate taxable entities. On a consolidated and separate company basis, the income tax provision consists of the following provision (benefit) components for the years ended December 31: MGE Energy MGE (In thousands) 2021 2020 2019 2021 2020 2019 Current payable: Federal $ ( 2,589 ) $ 4,179 $ 8,017 $ ( 3,434 ) $ 3,716 $ 7,616 State 3,002 5,095 4,647 3,163 4,790 4,608 Net-deferred: Federal ( 1,473 ) 6,181 3,510 ( 1,951 ) 4,756 2,242 State 6,310 4,182 3,702 5,605 3,787 3,044 Amortized investment tax credits ( 1,135 ) ( 214 ) ( 92 ) ( 1,135 ) ( 214 ) ( 92 ) Total income tax provision $ 4,115 $ 19,423 $ 19,784 $ 2,248 $ 16,835 $ 17,418 The consolidated income tax provision differs from the amount computed by applying the statutory federal income tax rate to income before income taxes, as follows: MGE Energy MGE 2021 2020 2019 2021 2020 2019 Statutory federal income tax rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % State income taxes, net of federal benefit 6.2 6.3 6.2 6.2 6.3 6.1 Amortized investment tax credits ( 1.5 ) ( 0.2 ) ( 0.1 ) ( 1.5 ) ( 0.2 ) ( 0.1 ) Credit for electricity from wind energy ( 6.0 ) ( 6.2 ) ( 5.7 ) ( 6.4 ) ( 6.8 ) ( 6.2 ) AFUDC equity, net ( 0.9 ) ( 1.2 ) ( 0.3 ) ( 1.0 ) ( 1.4 ) ( 0.3 ) Amortization of utility excess deferred tax (a) ( 14.8 ) ( 2.0 ) ( 2.4 ) ( 15.8 ) ( 2.2 ) ( 2.7 ) Other, net, individually insignificant ( 0.3 ) ( 0.3 ) ( 0.1 ) ( 0.3 ) ( 0.3 ) ( 0.1 ) Effective income tax rate 3.7 % 17.4 % 18.6 % 2.2 % 16.4 % 17.7 % (a) Included are impacts of the 2017 Tax Act for the regulated utility for excess deferred taxes recognized using a normalization method of accounting in recognition of IRS rules that restrict the rate at which excess deferred taxes may be returned to utility customers. For the years ended December 31, 2021, 2020 and 2019, MGE recognized $ 2.6 million, $ 2.2 million, and $ 2.6 million, respectively. Included in the 2021 rate settlement was a one-time return to customers of the electric portion of excess deferred taxes related to the 2017 Tax Act not restricted by IRS normalization rules. For the year ended December 31, 2021, MGE recognized $ 13.2 million. The significant components of deferred tax assets and liabilities that appear on the consolidated balance sheets as of December 31 are as follows: MGE Energy MGE (In thousands) 2021 2020 2021 2020 Deferred tax assets Investment in ATC $ 20,868 $ 21,688 $ — $ — Federal tax credits 39,161 19,199 39,161 20,080 Accrued expenses 11,053 11,115 11,047 11,105 Pension and other postretirement benefits 24,888 35,446 24,888 35,446 Deferred tax regulatory account 42,401 41,318 42,401 41,318 Derivatives 241 3,852 241 3,852 Leases 7,218 6,704 7,218 6,704 Other 17,390 14,073 17,442 14,125 Gross deferred income tax assets 163,220 153,395 142,398 132,630 Less valuation allowance — ( 38 ) — ( 38 ) Net deferred income tax assets $ 163,220 $ 153,357 $ 142,398 $ 132,592 Deferred tax liabilities Property-related $ 274,613 $ 257,397 $ 274,613 $ 257,397 Investment in ATC 52,731 51,518 — — Bond transactions 534 595 534 595 Pension and other postretirement benefits 34,781 45,658 34,781 45,658 Derivatives 241 3,852 241 3,852 Tax deductible prepayments 10,222 9,059 10,210 9,059 Leases 7,218 6,704 7,218 6,704 Other 14,029 10,045 13,686 9,717 Gross deferred income tax liabilities 394,369 384,828 341,283 332,982 Deferred income taxes, net $ 231,149 $ 231,471 $ 198,885 $ 200,390 The components of federal and state tax benefit carryovers as of December 31, are as follows: MGE Energy MGE (In thousands) 2021 2020 2021 2020 Federal tax credits $ 39,161 $ 19,199 $ 39,161 $ 20,080 State net operating losses 3 621 3 621 Valuation allowances for state net operating losses ( 3 ) ( 621 ) ( 3 ) ( 621 ) Federal tax credit carryovers begin to expire in 2040 and state net operating loss carryforwards expire in 2023. Federal tax credits represent the deferred tax asset and net operating loss amounts represent the tax loss that is carried forward. The state valuation allowance reduces MGE Energy’s and MGE’s state carryforward losses to estimated realizable value due to the uncertainty of future income in various state tax jurisdictions. b. Accounting for Uncertainty in Income Taxes - MGE Energy and MGE. The difference between the tax benefit amount taken on prior year tax returns, or expected to be taken on a current year tax return, and the tax benefit amount recognized in the financial statements is accounted for as an unrecognized tax benefit. A tabular reconciliation of unrecognized tax benefits and interest is as follows: (In thousands) Unrecognized Tax Benefits: 2021 2020 2019 Unrecognized tax benefits, January 1, $ 2,281 $ 2,093 $ 1,949 Additions based on tax positions related to the current year 714 796 741 Additions based on tax positions related to the prior years - - 84 Reductions based on tax positions related to the prior years ( 642 ) ( 608 ) ( 681 ) Unrecognized tax benefits, December 31, $ 2,353 $ 2,281 $ 2,093 (In thousands) Interest on Unrecognized Tax Benefits: 2021 2020 2019 Accrued interest on unrecognized tax benefits, January 1, $ 154 $ 176 $ 191 Reduction in interest expense on uncertain tax positions ( 98 ) ( 124 ) ( 137 ) Interest expense on uncertain tax positions 94 102 122 Accrued interest on unrecognized tax benefits, December 31, $ 150 $ 154 $ 176 Unrecognized tax benefits are classified with "Other deferred liabilities" on the consolidated balance sheets. The interest component recoverable in rates is offset by a regulatory asset. As of December 31, 2021, 2020, and 2019, MGE Energy and MGE have an unrecognized tax benefit primarily related to temporary tax differences associated with the change in income tax method of accounting for electric generation and electric and gas distribution repairs. In addition, as of December 31, 2019 , MGE Energy and MGE have unrecognized tax benefits relating to permanent differences and tax credits of less than $ 0.1 million. As of December 31, 2021 and 2020 , there were no unrecognized tax benefits relating to permanent differences and tax credits. The unrecognized tax benefits as of December 31, 2021 , are not expected to significantly increase or decrease within the next twelve months. In addition, statutes of limitations will expire for MGE Energy and MGE tax returns. The impact of the statutes of limitations expiring is not anticipated to be material. The following table shows tax years that remain subject to examination by major jurisdiction: Taxpayer Open Years MGE Energy and consolidated subsidiaries in federal return 2018 through 2021 MGE Energy Wisconsin combined reporting corporation return 2017 through 2021 |
Pension Plans and Other Postret
Pension Plans and Other Postretirement Benefits | 12 Months Ended |
Dec. 31, 2021 | |
Compensation and Retirement Disclosure [Abstract] | |
Pension Plans and Other Postretirement Benefits | 11. Pension Plans and Othe r Postretirement Benefits - MGE Energy and MGE. MGE maintains qualified and nonqualified pension plans, health care, and life insurance benefits, and defined contribution 401(k) benefit plans for its employees and retirees. MGE's costs for the 401(k) plans were $ 5.1 million, $ 4.7 million, and $ 4.4 million for the years ended December 31, 2021, 2020, and 2019, respectively. A measurement date of December 31 is utilized for all pension and postretirement benefit plans. All employees hired after December 31, 2006, have been enrolled in the defined contribution pension plan rather than the defined benefit pension plan previously in place. a. Benefit Obligations and Plan Assets. (In thousands) Pension Benefits Other Postretirement Benefits Change in Benefit Obligations: 2021 2020 2021 2020 Net benefit obligation as of January 1, $ 461,215 $ 410,651 $ 86,360 $ 80,901 Service cost 5,730 5,296 1,448 1,264 Interest cost 9,109 12,210 1,549 2,278 Plan participants' contributions — — 992 1,009 Actuarial loss (gain) (a) 3,871 50,325 ( 685 ) 5,907 Gross benefits paid ( 19,259 ) ( 17,267 ) ( 5,405 ) ( 5,245 ) Less: federal subsidy on benefits paid (b) — — 267 246 Benefit obligation as of December 31, $ 460,666 $ 461,215 $ 84,526 $ 86,360 Change in Plan Assets: Fair value of plan assets as of January 1, $ 429,538 $ 386,033 $ 51,735 $ 48,889 Actual return on plan assets 61,487 58,935 6,814 6,514 Employer contributions 2,187 1,837 708 568 Plan participants' contributions — — 992 1,009 Gross benefits paid ( 19,259 ) ( 17,267 ) ( 5,405 ) ( 5,245 ) Fair value of plan assets at end of year 473,953 429,538 54,844 51,735 Funded Status as of December 31, $ 13,287 $ ( 31,677 ) $ ( 29,682 ) $ ( 34,625 ) (a) In 2020, lower discount rates were the primary driver of the actuarial loss. (b) In 2003, the Medicare Prescription Drug, Improvement and Modernization Act of 2003 was signed into law authorizing Medicare to provide prescription drug benefits to retirees. For the years ended December 31, 2021 and 2020, the subsidy due to MGE was $ 0.3 million and $ 0.2 million, respectively. The accumulated benefit obligation for the defined benefit pension plans as of December 31, 2021 and 2020, was $ 431.3 million and $ 430.3 million, respectively. The amounts recognized in the consolidated balance sheets to reflect the funded status of the plans as of December 31 are as follows: Pension Benefits Other Postretirement Benefits (In thousands) 2021 2020 2021 2020 Long-term asset $ 58,757 $ 13,873 $ — $ — Current liability ( 2,342 ) ( 2,139 ) — — Long-term liability ( 43,128 ) ( 43,411 ) ( 29,682 ) ( 34,625 ) Net liability $ 13,287 $ ( 31,677 ) $ ( 29,682 ) $ ( 34,625 ) The following table shows the amounts that have not yet been recognized in our net periodic benefit cost as of December 31 and are recorded as regulatory assets in the consolidated balance sheets: Pension Benefits Other Postretirement Benefits (In thousands) 2021 2020 2021 2020 Net actuarial loss $ 57,777 $ 92,553 $ 6,256 $ 10,986 Prior service benefit ( 20 ) ( 144 ) ( 297 ) ( 1,816 ) Transition obligation — — 12 15 Total $ 57,757 $ 92,409 $ 5,971 $ 9,185 The projected benefit obligation and fair value of plan assets for pension plans with a projected benefit obligation in excess of plan assets were as follows : (In thousands) Pension Benefits Projected Benefit Obligation in Excess of Plan Assets 2021 2020 Projected benefit obligation, end of year $ 45,470 $ 45,550 Fair value of plan assets, end of year — — The accumulated benefit obligation and fair value of plan assets with an accumulated benefit obligation in excess of plan assets were as follows: (In thousands) Pension Benefits Other Postretirement Benefits Accumulated Benefit Obligation in Excess of Plan Assets 2021 2020 2021 2020 Accumulated benefit obligation, end of year $ 43,831 $ 43,384 $ 84,526 $ 86,360 Fair value of plan assets, end of year — — 54,844 51,735 b. Net Periodic Benefit Cost. (In thousands) Pension Benefits Other Postretirement Benefits Components of Net Periodic Benefit Cost: 2021 (a) 2020 (a) 2019 (a) 2021 (a) 2020 (a) 2019 (a) Service cost $ 5,730 $ 5,296 $ 4,692 $ 1,448 $ 1,264 $ 1,110 Interest cost 9,109 12,210 14,302 1,549 2,278 2,893 Expected return on assets ( 29,487 ) ( 27,229 ) ( 22,786 ) ( 3,277 ) ( 3,154 ) ( 2,723 ) Amortization of: Transition obligation — — — 3 3 3 Prior service (credit) cost ( 124 ) ( 114 ) ( 117 ) ( 1,518 ) ( 2,669 ) ( 2,669 ) Actuarial loss 6,646 5,357 7,379 493 217 401 Net periodic benefit cost (credit) $ ( 8,126 ) $ ( 4,480 ) $ 3,470 $ ( 1,302 ) $ ( 2,061 ) $ ( 985 ) (a) During 2019, MGE deferred approximately $ 6.2 million of pension and other postretirement costs. During 2021 and 2020 , MGE collected approximately $ 4.3 million and $ 0.9 million, respectively, of pension and other postretirement costs, which reduced the amount deferred in prior years. The impact of the deferral has not been reflected in the table above. See Footnote 8 for further information. During the year ended December 30, 2021, MGE deferred $ 8.1 million of savings from 2021 employee benefit plan costs and recorded as a regulatory liability. The deferred savings has not been reflected in the table above. See Footnote 8 for additional information. The components of net periodic benefit cost, other than the service cost component, are recorded in "Other income, net" on the consolidated statements of income. The service cost component is recorded in "Other operations and maintenance" on the consolidated statements of income. MGE has regulatory treatment and recognizes regulatory assets or liabilities for timing differences between when net periodic benefit costs are recovered and when costs are recognized. c. Plan Assumptions. The weighted-average assumptions used to determine the benefit obligations were as follows for the years ended December 31: Pension Benefits Other Postretirement Benefits 2021 2020 2021 2020 Discount rate 2.94 % 2.70 % 2.85 % 2.52 % Rate of compensation increase 3.19 % 3.22 % N/A N/A Assumed health care cost trend rates: Health care cost trend rate assumed for next year N/A N/A 5.75 % 5.75 % Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) N/A N/A 4.75 % 4.75 % Year that the rate reaches the ultimate trend rate N/A N/A 2027 2027 MGE uses individual spot rates, instead of a weighted average of the yield curve spot rates, for measuring the service cost and interest cost components of net periodic benefit cost. The weighted-average assumptions used to determine the net periodic cost were as follows for the years ended December 31: Pension Benefits Other Postretirement Benefits 2021 2020 2019 2021 2020 2019 Discount rate 2.70 % 3.42 % 4.32 % 2.52 % 3.30 % 4.24 % Expected rate of return on plan assets 7.00 % 7.20 % 7.20 % 6.61 % 6.75 % 6.72 % Rate of compensation increase 3.23 % 3.26 % 3.25 % N/A N/A N/A MGE employs a building-block approach in determining the expected long-term rate of return for asset classes. Historical markets are studied and long-term historical relationships among asset classes are analyzed, consistent with the widely accepted capital market principle that assets with higher volatility generate a greater return over the long run. Current market factors, such as interest rates and dividend yields, are evaluated before long-term capital market assumptions are determined. The expected long-term nominal rate of return for plan assets is primarily a function of expected long-term real rates of return for component asset classes and the plan's target asset allocation in conjunction with an inflation assumption. Peer data and historical returns are reviewed to check for appropriateness. d. Investment Strategy. MGE employs a total return investment approach whereby a mix of equities, fixed income, and real estate investments are used to maximize the expected long-term return of plan assets for a prudent level of risk. Risk tolerance is established through careful consideration of plan liabilities, plan-funded status, and corporate financial condition. The investment portfolio contains a diversified blend of equity, fixed income, and real estate investments. Investment risk is measured and monitored on an ongoing basis through periodic investment portfolio reviews and liability measurements. The asset allocation for MGE's pension plans as of December 31, 2021 and 2020, and the target allocation for 2022, by asset category, follows: Target Percentage of Plan Allocation 2021 2020 Equity securities (a) 63.0 % 65.0 % 69.0 % Fixed income securities 30.0 % 29.0 % 25.0 % Real estate 7.0 % 6.0 % 6.0 % Total 100.0 % 100.0 % 100.0 % (a) Target allocations for equity securities are broken out as follows: 45.5 % United States equity and 17.5 % non-United States equity. The fair value of plan assets for the postretirement benefit plans is $ 54.8 million and $ 51.7 million as of December 31, 2021 and 2020, respectively. Of this amount, $ 48.7 million and $ 45.6 million as of December 31, 2021 and 2020, respectively, were held in the master pension trust and are allocable to postretirement health expenses. The target asset allocation and investment strategy for the portion of assets held in the master pension trust are the same as that explained for MGE's pension plans. The remainder of postretirement benefit assets are held either in an insurance continuance fund for the payment of retiree life benefits or health benefit trusts for payment of retiree health premiums. The asset allocation for the insurance continuance fund is determined by the life insurer. The target asset allocation for the health benefit trusts are established based on a similar investment strategy as assets held in the master pension trust, with consideration for liquidity needs in the health benefit trusts. e. Concentrations of Credit Risk. MGE evaluated its pension and other postretirement benefit plans' asset portfolios for the existence of significant concentrations of credit risk as of December 31, 2021. Types of concentrations that were evaluated include, but are not limited to, investment concentrations in a single entity, type of industry, and foreign country. As of December 31, 2021 , there were no significant concentrations (defined as greater than 10 percent of plan assets) of risk in MGE pension and postretirement benefit plan assets. f. Fair Value Measurements of Plan Assets. Pension and other postretirement benefit plan investments are recorded at fair value. See Footnote 19 for more information regarding the fair value hierarchy. The following descriptions are the categories of underlying plan assets held within the pension and other postretirement benefit plans as of December 31, 2021: Cash and Cash Equivalents – This category includes highly liquid investments with maturities of less than three months which are traded in active markets. Equity Securities – These securities consist of U.S. and international stock funds. The U.S. stock funds are primarily invested in domestic equities. Securities in these funds are typically priced using the closing price from the applicable exchange, NYSE, Nasdaq, etc. The international funds are composed of international equities. Securities are priced using the closing price from the appropriate local stock exchange. Fixed Income Securities – These securities consist of U.S. bond funds and short-term funds. U.S. bond funds are priced by a pricing agent using inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. The short-term funds are valued initially at cost and adjusted for amortization of any discount or premium. Real Estate – Real estate funds are funds with a direct investment in pools of real estate properties. These funds are valued by investment managers on a periodic basis using pricing models that use independent appraisals. The fair value of real estate investments is determined using net asset value. Insurance Continuance Fund (ICF) – The ICF is a supplemental retirement plan that includes assets that have been segregated and restricted to pay retiree term life insurance premiums. Fixed Rate Fund – The Fixed Rate fund is supported by an underlying portfolio of fixed income securities, including public bonds, commercial mortgages, and private placement bonds. Public market data and GAAP reported market values are used when available to determine fair value. All of the fair values of MGE's plan assets are measured using net asset value, except for cash and cash equivalents which are considered level 1 investments. The fair values of MGE's plan assets by asset category as of December 31 are as follows: (In thousands) 2021 2020 Cash and Cash Equivalents $ 1,428 $ 1,180 Equity Securities: U.S. Large Cap 162,060 151,218 U.S. Mid Cap 38,755 37,389 U.S. Small Cap 47,657 50,456 International Blend 87,781 87,461 Fixed Income Securities: Short-Term Fund 5,222 4,215 High Yield Bond 25,190 22,683 Long Duration Bond 119,867 92,657 Real Estate 37,170 30,005 Insurance Continuance Fund 1,599 1,506 Fixed Rate Fund 2,068 2,503 Total $ 528,797 $ 481,273 g. Expected Cash Flows. MGE does no t expect to need to make any required contributions to the qualified plans for 2022. The contributions for years after 2022 are not yet currently estimated. MGE has adopted the asset smoothing as permitted in accordance with the Pension Protection Act of 2006, including modifications made by WRERA. Due to uncertainties in the future economic performance of plan assets, discount rates, and other key assumptions, estimated contributions are subject to change. MGE may also elect to make additional discretionary contributions. In 2021, MGE made $ 6.9 million in employer contributions to its pension and postretirement plans. h. Benefit Payments. The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid as follows: Pension Other Postretirement Benefits (In thousands) Pension Benefits Gross Postretirement Benefits Expected Medicare Part D Subsidy Net Postretirement Benefits 2022 $ 19,736 $ 4,713 $ ( 304 ) $ 4,409 2023 20,474 4,982 ( 333 ) 4,649 2024 21,197 5,281 ( 363 ) 4,918 2025 21,897 5,533 ( 395 ) 5,138 2026 22,497 5,567 ( 430 ) 5,137 2027 - 2031 117,862 27,651 ( 2,541 ) 25,110 |
Share-Based Compensation
Share-Based Compensation | 12 Months Ended |
Dec. 31, 2021 | |
Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | |
Share-Based Compensation | 12. Share-Based Compe nsation - MGE Energy and MGE. In 2020, MGE Energy shareholders approved the 2021 Long-Term Incentive Plan (the 2021 Incentive Plan). It provides for the issuance of up to 500,000 shares of MGE Energy common stock in connection with awards made under the 2021 Incentive Plan. The 2021 Incentive Plan authorizes awards of restricted stock, restricted stock units, performance units, and dividend equivalents, or any combination of the foregoing for eligible employees and non-employee directors. The 2020 Performance Unit Plan (the 2020 Plan) was adopted in February 2020 for eligible employees. Plan participants may receive awards of performance units, restricted units, or both. Prior to the adoption of the 2020 plan, eligible employees could receive awards of performance units under the 2006 Performance Unit Plan. Under the 2013 Director Incentive Plan, eligible non-employee directors could receive awards of performance units. During the years ended December 31, 2021, 2020 and 2019, MGE recorded $ 2.9 million, $ 1.3 million, and $ 3.0 million, respectively, related to share-based compensation awards under the 2006 Performance Unit Plan, the 2020 Performance Unit Plan, the 2013 Director Incentive Plan, and the 2021 Incentive Plan in "Other operations and maintenance" on the consolidated statements of income. 2013 Director Incentive Plan and 2006 Performance Unit Plan - Liability Awards - Under MGE Energy's 2013 Director Incentive Plan and its 2006 Performance Unit Plan, non-employee directors and eligible employees, respectively, could receive performance units that entitled the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the performance period set in the award. In accordance with the plans' provisions. These awards are subject to prescribed vesting schedules and must be settled in cash. Accordingly, no shares of common stock will be issued in connection with those plans. On the grant date, the cost of the director or employee services received in exchange for a performance unit award is measured based on the current market value of MGE Energy common stock. The fair value of the awards is remeasured quarterly, including as of December 31, 2021, as required by applicable accounting standards. Changes in fair value as well as the original grant are recognized as compensation cost. Since this amount is remeasured throughout the vesting period, the compensation cost is subject to variability. For nonretirement eligible employees under the 2006 Performance Unit Plan, stock-based compensation costs are accrued and recognized using the graded vesting method. Compensation cost for retirement eligible employees or employees that will become retirement eligible during the vesting schedule are recognized on an abridged horizon as retirement eligibility accelerates vesting. Payouts under the 2013 Director Incentive Plan are subject to a three -year vesting schedule. Payouts under the 2006 Performance Unit Plan are subject to a five -year vesting schedule. The following activity occurred: 2021 Director Performance Nonvested awards January 1, 4,286 17,420 Granted — — Vested ( 2,814 ) ( 11,660 ) Nonvested awards December 31, 1,472 5,760 No cash settlements have occurred on the awards shown in the table above as cash payments are only made at the end of the period covered by the awards. In January 2021, cash payments of $ 1.9 million were distributed relating to awards that were granted under the plans in 2018, for the 2013 Director Incentive Plan, and in 2016, for the 2006 Performance Unit Plan. Restricted Stock Units - Equity Awards - Payouts of 2021 restricted stock units are based on the expiration of a three-year time-vesting period. Restricted stock units granted in 2021 are to be paid out in shares of MGE Energy common stock and are accounted for as equity awards. The fair value of each restricted stock unit granted is based on the closing market price of one share of MGE Energy common stock on the grant date of the award. Compensation expense is recorded ratably over the performance period based on the fair value of the awards on the grant date. The following activity occurred: 2021 Units Weighted Average Grant Date Fair Value (per share) Nonvested awards January 1, — N/A Granted 16,267 $ 65.83 Vested — Undistributed vested awards (a) ( 3,141 ) $ 65.83 Nonvested awards December 31, 13,126 $ 65.83 (a) Represents restricted stock units that vested but were not distributed to retirement-eligible employees during 2021. In February 2022, MGE issued 15,931 restricted stock units to eligible employees and non-employee directors. Restricted Stock Units - Liability Awards - Payouts of restricted stock units granted prior to 2021 are based on the expiration of a three-year time-vesting period and will be paid out in cash and accounted for as a liability award. Compensation expense is recorded ratably over the performance period based on the fair value of the awards at each reporting period. The following activity occurred: 2021 Nonvested awards January 1, 7,003 Granted — Vested — Undistributed vested awards (b) ( 939 ) Nonvested awards December 31, 6,064 (b) Represents restricted stock units that vested but were not distributed to retirement-eligible employees during 2021. Performance Units - Liability Awards - Performance units under the 2020 Plan 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. Performance units under the 2021 Incentive Plan can be paid out in shares of MGE Energy common stock, cash or a combination of cash and stock. MGE assumes it will make future payouts of its performance units granted in 2021 and 2020 in cash; therefore, these performance units are accounted for as liability awards. Compensation expense for these performance units is recorded ratably over the performance period based on the fair value of the awards at each reporting period. The payout is based upon achievement of specified performance goals during a performance period set by the Compensation Committee of MGE Energy's Board of Directors. Awards are subject to vesting provisions providing for 100% vesting at the end of the performance period. Compensation cost for retirement eligible employees or employees that will become retirement eligible during the vesting schedule are recognized on an abridged horizon as retirement eligibility accelerates vesting. The performance units contain market and performance conditions. The market condition is based on total shareowner return relative to an investor-owned utility peer group. The performance condition is based on achievement of targets specified in the award agreement (such as an earnings growth target). The fair value of each performance unit is based on the fair value of the underlying common stock on the grant date and the probability of satisfying the market and performance conditions contained in the award agreement during the three -year performance period. The actual payments upon vesting depends upon actual performance and may range from zero to 200 % of the granted number of performance units. The following activity occurred : 2021 Nonvested awards January 1, 7,003 Granted 10,187 Vested — Undistributed vested awards (c) ( 3,320 ) Nonvested awards December 31, 13,870 Weighted average fair Value of each nonvested award $ 104.76 Weighted average estimated payout % based on performance criteria 127.4 % (c) Represents performance units that vested but were not distributed to retirement-eligible employees during 2021. In February 2022, MGE issued 10,395 performance units under the 2021 Incentive Plan to eligible employees. |
Notes Payable to Banks, Commerc
Notes Payable to Banks, Commercial Paper, and Lines of Credit | 12 Months Ended |
Dec. 31, 2021 | |
Debt Disclosure [Abstract] | |
Notes Payable to Banks, Commercial Paper, and Lines of Credit | 13. Notes Payable to Ban ks, Commercial Paper, and Lines of Credit. a. MGE Energy. As of December 31, 2021 , MGE Energy had an unsecured, committed revolving line of credit of $ 50 million expiring February 7, 2024. As of December 31, 2021 , no borrowings were outstanding under this facility. The credit agreement requires MGE Energy to maintain a ratio of its consolidated indebtedness to consolidated total capitalization not to exceed a maximum of 65 %. A change in control constitutes a default under the agreement. Change in control events are defined as (i) a failure by MGE Energy to hold 100 % of the outstanding voting equity interest in MGE or (ii) the acquisition of beneficial ownership of 30 % or more of the outstanding voting stock of MGE Energy by one person or two or more persons acting in concert. As of December 31, 2021, MGE Energy was in compliance with the covenant requirements of the credit agreement. b. MGE. For short-term borrowings, MGE generally issues commercial paper (issued at the prevailing discount rate at the time of issuance), which is supported by unused committed bank lines of credit. As of December 31, 2021 , MGE had two unsecured, committed revolving lines of credit for a total of $ 100 million expiring February 7, 2024. As of December 31, 2021 , no borrowings were outstanding under these facilities; however, there was $ 5.5 million in commercial paper outstanding. As of December 31, 2021 , MGE had $ 0.7 million of letters of credit issued inside credit facilities. The credit agreements require MGE to maintain a ratio of consolidated debt to consolidated total capitalization not to exceed a maximum of 65 %. The ratio calculation excludes assets, liabilities, revenues, and expenses included in MGE's financial statements as the result of the consolidation of VIEs, such as MGE Power West Campus and MGE Power Elm Road. A change in control constitutes a default under the agreements. Change in control events are defined as (i) a failure by MGE Energy to hold 100 % of the outstanding voting equity interest in MGE or (ii) the acquisition of beneficial ownership of 30 % or more of the outstanding voting stock of MGE Energy by one person or two or more persons acting in concert. As of December 31, 2021, MGE was in compliance with the covenant requirements of the credit agreements. c. Short-Term Borrowings - MGE Energy and MGE. Information concerning short-term borrowings is shown below: (In thousands) MGE Energy (a) MGE As of December 31, 2021 2020 2021 2020 Available capacity under line of credit $ 143,815 $ 96,815 $ 93,815 $ 46,815 Short-term debt outstanding $ 5,500 $ 52,500 $ 5,500 $ 52,500 Letters of credit issued inside credit facilities $ 685 $ 685 $ 685 $ 685 Weighted-average interest rate 0.15 % 0.15 % 0.15 % 0.15 % Year Ended December 31, Maximum short-term borrowings $ 64,000 $ 52,500 $ 64,000 $ 52,500 Average short-term borrowings $ 28,583 $ 6,393 $ 28,583 $ 6,393 Weighted-average interest rate 0.15 % 0.43 % 0.15 % 0.43 % (a) MGE Energy short-term borrowings include MGE Energy and MGE lines of credit and MGE commercial paper. |
Long-Term Debt
Long-Term Debt | 12 Months Ended |
Dec. 31, 2021 | |
Debt Disclosure [Abstract] | |
Long-Term Debt | 14. Long-Term De bt - MGE Energy and MGE. a. Long-Term Debt. December 31, (In thousands) 2021 2020 First Mortgage Bonds: (a) 7.70 %, 2028 Series $ 1,200 $ 1,200 Tax Exempt Debt: 2.05 %, 2023 Series, Industrial Development Revenue Bonds 19,300 19,300 Medium-Term Notes: (c) 6.12 %, due 2028 20,000 20,000 7.12 %, due 2032 25,000 25,000 6.247 %, due 2037 25,000 25,000 Total Medium-Term Notes 70,000 70,000 Other Long-Term Debt: (d) 3.09 %, due 2023 (e) 30,000 30,000 3.29 %, due 2026 (e) 15,000 15,000 3.11 %, due 2027 (e) 30,000 30,000 2.94 %, due 2029 (e) 50,000 50,000 2.48 %, due 2031 (e)(b) 60,000 — 5.68 %, due 2033 (f) 21,510 22,762 5.19 %, due 2033 (f) 14,133 14,985 2.63 %, due 2033 (e)(b) 40,000 — 5.26 %, due 2040 (e) 15,000 15,000 5.04 %, due 2040 (g) 30,139 31,806 4.74 %, due 2041 (g) 19,167 20,167 4.38 %, due 2042 (e) 28,000 28,000 4.42 %, due 2043 (e) 20,000 20,000 4.47 %, due 2048 (e) 20,000 20,000 3.76 %, due 2052 (e) 40,000 40,000 4.19 %, due 2048 (e) 60,000 60,000 4.24 %, due 2053 (e) 20,000 20,000 4.34 %, due 2058 (e) 20,000 20,000 Total Other Long-Term Debt 532,949 437,720 Long-term debt due within one year ( 4,889 ) ( 4,771 ) Unamortized discount and debt issuance costs ( 4,349 ) ( 4,146 ) Total Long-Term Debt $ 614,211 $ 519,303 (a) MGE's utility plant is subject to the lien of its Indenture of Mortgage and Deed of Trust, under which its first mortgage bonds are issued. The Mortgage Indenture provides that dividends or any other distribution or purchase of MGE shares may not be made if the aggregate amount thereof since December 31, 1945, would exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2021, approximately $ 604.3 million was available for the payment of dividends under this covenant. (b) In May 2021, MGE entered into a private placement Note Purchase Agreement in which it committed to issue $60 million of new long-term debt (Series A) and $40 million of new long-term debt (Series B). Funding occurred on June 15, 2021, for Series B and August 27, 2021, for Series A. The proceeds of the debt financing were used to assist with capital expenditures and other corporate obligations. (c) The indenture under which MGE's Medium-Term notes are issued provides that those notes will be entitled to be equally and ratably secured in the event that MGE issues any additional first mortgage bonds. (d) Unsecured notes issued pursuant to various Note Purchase Agreements with one or more purchasers. The notes are not issued under, or governed by, MGE's Indenture dated as of September 1, 1998, which governs MGE's Medium-Term Notes. (e) Issued by MGE. Under that Note Purchase Agreement: (i) note holders have the right to require MGE to repurchase their notes at par in the event of an acquisition of beneficial ownership of 30 % or more of the outstanding voting stock of MGE Energy, (ii) MGE must maintain a ratio of its consolidated indebtedness to consolidated total capitalization not to exceed a maximum of 65 %, and (iii) MGE cannot issue "Priority Debt" in an amount exceeding 20 % of its consolidated assets. Priority Debt is defined as any indebtedness of MGE secured by liens other than specified liens permitted by the Note Purchase Agreement and certain unsecured indebtedness of certain subsidiaries. As of December 31, 2021 , MGE was in compliance with the covenant requirements. (f) Issued by MGE Power West Campus. The Note Purchase Agreements require MGE Power West Campus to maintain a projected debt service coverage ratio of not less than 1.25 to 1.00, and debt to total capitalization ratio of not more than 0.65 to 1.00. The notes are secured by a collateral assignment of lease payments that MGE is making to MGE Power West Campus for use of the WCCF pursuant to a long-term lease. As of December 31, 2021 , MGE Power West Campus was in compliance with the covenant requirements. (g) Issued by MGE Power Elm Road. The Note Purchase Agreement requires MGE Power Elm Road to maintain a projected and actual debt service coverage ratio at the end of any calendar quarter of not less than 1.25 to 1.00 for the trailing 12-month period. The notes are secured by a collateral assignment of lease payments that MGE is making to MGE Power Elm Road for use of the Elm Road Units pursuant to long-term leases. As of December 31, 2021 , MGE Power Elm Road was in compliance with the covenant requirements. b. Long-Term Debt Maturities. Below is MGE Energy's and MGE's aggregate maturities for all long-term debt for years following December 31, 2021. (In thousands) 2022 2023 2024 2025 2026 Thereafter Long-term debt maturities $ 4,889 $ 54,314 $ 5,146 $ 5,285 $ 20,433 $ 533,382 MGE includes long-term debt held by MGE Power Elm Road and MGE Power West Campus in the consolidated financial statements (see Footnote 3 for further information regarding these VIEs). |
Common Equity
Common Equity | 12 Months Ended |
Dec. 31, 2021 | |
Equity [Abstract] | |
Common Equity | 15. Common Equ ity. a. Common Stock - MGE Energy and MGE. MGE Energy sells shares of its common stock through its Direct Stock Purchase and Dividend Reinvestment Plan (the Stock Plan). Those shares may be newly issued shares or shares that are purchased in the open market by an independent agent for participants in the Stock Plan. The volume and timing of share repurchases in the open market depends upon the level of dividend reinvestment and optional share purchases made by plan participants. As a result, there is no specific maximum number of shares to be repurchased and no specified termination date for the repurchases. All sales under the Stock Plan are covered by a shelf registration statement that MGE Energy filed with the SEC. For the years ended December 31, 2021 and 2020 , MGE Energy issued no new shares of common stock under the Stock Plan. In May 2020, MGE Energy issued 1.5 million shares of its common stock in an underwritten offering. MGE Energy received proceeds, net of underwriter fees and issuance costs, of $ 79.6 million from the issuance and sale of those shares. The net proceeds were used for general corporate purposes, including funding capital expenditures made by MGE. During the years ended December 31, 2021 and 2020, MGE Energy paid $ 54.8 million (or $ 1.52 per share) and $ 51.7 million (or $ 1.45 per share), respectively, in cash dividends on its common stock. Dividend payments by MGE to MGE Energy are subject to restrictions arising under a PSCW rate order and, to a lesser degree, MGE's first mortgage bonds. The PSCW order restricts any dividends, above the PSCW authorized amount that MGE may pay MGE Energy if MGE's common equity ratio, calculated in the manner used in the rate proceeding, is less than 55 %. This restriction did not restrict MGE's payment of dividends in 2021. See Footnote 14 for further discussion of the mortgage indenture covenants regarding the payment of dividends. During the year ended December 31, 2021, MGE paid $ 5.0 million in cash dividends to MGE Energy. During the year ended December 31, 2020 , MGE paid no dividends to MGE Energy. b. Dilutive Shares Calculation - MGE Energy. As of December 31, 2021, 3,668 shares were included in the calculation of diluted earnings per share related to nonvested equity awards. See Footnote 12 for additional information on shared-based compensation awards. |
Commitments and Contingencies
Commitments and Contingencies | 12 Months Ended |
Dec. 31, 2021 | |
Commitments and Contingencies Disclosure [Abstract] | |
Commitments and Contingencies | 16. Commitments and Contin gencies. a. Environmental - MGE Energy and MGE. Columbia In February 2021, MGE and the other co-owners of Columbia announced plans to retire that facility. The co-owners intend to retire Unit 1 by the end of 2023 and Unit 2 by the end of 2024. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. Effects of environmental compliance discussed below will depend upon the final retirement dates approved and compliance requirement dates. Water Quality Water quality regulations promulgated by the EPA and WDNR in accordance with the Federal Water Pollution Control Act, commonly known as the Clean Water Act (CWA), impose restrictions on discharges of various pollutants into surface waters. The CWA also regulates surface water quality issues that affect aquatic life, such as water temperatures, chemical concentrations, intake structures, and wetlands filling. The CWA also includes discharge standards, which require the use of effluent-treatment processes equivalent to categorical "best practicable" or "best available" technologies. The CWA regulates discharges from "point sources," such as power plants, by establishing discharge limits via water discharge permits. MGE's power plants operate under Wisconsin Pollution Discharge Elimination System (WPDES) permits issued by the WDNR to ensure compliance with these discharge limits. Permits are subject to periodic renewal. EPA's Effluent Limitations Guidelines and Standards for Steam Electric Power Generating Point Source Category The EPA has promulgated water Effluent Limitations Guidelines (ELG) and standards for new and existing steam electric power plants that primarily require the reduction of metals and other pollutants in wastewater. MGE’s Columbia plant and Elm Road Units are subject to this rule. In July 2021, the PSCW approved a Certificate of Authority (CA) application, filed by MGE and the other owners of Columbia, which commits to close Columbia's wet pond system to comply with the Coal Combustions Residuals (CCR) Rule (as described in further detail in the CCR section below). By closing the wet pond system Columbia will be in compliance with ELG requirements. The Elm Road Units must satisfy the ELG rule's requirements no later than December 2023, as determined by the permitting authority. In December 2021, the PSCW approved a CA application for installation of additional wastewater treatment equipment to comply with the ELG Rule. MGE's share of the estimated costs to comply with the rule is estimated to be approximately $ 4 million. Construction is expected to begin in 2022. Based on previous treatment of environmental compliance projects, management believes that any compliance costs will be recovered in future rates. EPA Cooling 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 (BTA) standards to reduce mortality from entrainment (drawing aquatic life into a plant's cooling system) and impingement (trapping aquatic life on screens). The EPA finalized its Section 316(b) rule for existing facilities in 2014. Section 316(b) requirements are implemented in Wisconsin through modifications to plants' WPDES permits, which govern plant wastewater discharges. WCCF, Blount, and Columbia are considered existing plants under this rule. WCCF employs a system that meets the Section 316(b) rule. Blount's WPDES permit assumes that the plant meets BTA standards for the duration of the permit, which expires in 2023. Before the next permit renewal, MGE is required to complete an entrainment study and recommend a BTA along with alternative technologies considered. MGE completed the entrainment study in 2021 and submitted the results to the WDNR. The WDNR will make the final BTA determination and include any BTA requirements in Blount's next permit renewal, which is expected to be completed by the end of 2022 and effective in 2023. Management believes that the BTA determination at Blount will not be material for MGE. Section 316(b) applies to river intakes at the Columbia plant. Columbia's operator received a permit in 2019 requiring studies of intake structures to be submitted to the WDNR by November 2023 to help determine BTA. BTA improvements may not be required given that Columbia is scheduled to retire both units by the end of 2024. MGE will continue to work with Columbia’s operator to evaluate all regulatory requirements applicable to the planned retirements. Management believes that the Section 316(b) rule will not have a material effect on its existing plants and that any compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects. Air Quality Federal and state air quality regulations impose restrictions on various emissions, including emissions of particulate matter (PM), sulfur dioxide (SO 2 ), nitrogen oxides (NO x ), and other pollutants, and require permits for operation of emission sources. These permits have been obtained by MGE and must be renewed periodically. Current EPA initiatives under the Clean Air Act, including the Cross-State Air Pollution Rule (CSAPR) and National Ambient Air Quality Standards (NAAQS), have the potential to result in additional operating and capital expenditure costs for MGE. EPA's Greenhouse Gas (GHG) Reduction Guidelines under the Clean Air Act 111(d) Rule In January 2021, the U.S. Court of Appeals for the District of Columbia Circuit (D.C. Circuit) vacated and remanded to the EPA the Affordable Clean Energy Rule (ACE Rule) and repealed the predecessor Clean Power Plan Rule (CPP Rule), both of which regulated greenhouse gas emissions from existing electric generation units pursuant to Section 111(d) of the Clean Air Act. As a result of these legal proceedings, neither the CPP nor ACE rules are currently in effect. In October 2021, as part of the Biden administration's Unified Agenda, the EPA announced their intention to introduce a proposed GHG rule by July 2022. The EPA has described the pending proposed rule as guidelines for states to regulate GHGs under Section 111(d). MGE will continue to monitor and evaluate developments to this rule. National Ambient Air Quality Standards (NAAQS) and Related Rules The EPA's NAAQS regulations have been developed to set ambient levels of six pollutants to protect sensitive human populations (primary NAAQS) and the environment (secondary NAAQS) from the negative effects of exposure to these pollutants at higher levels. The Clean Air Act requires that the EPA periodically review, and adjust as necessary, the NAAQS for these six air pollutants. The EPA's NAAQS review can result in a lowering of the allowed ambient levels of a pollutant, a change in how the pollutant is monitored, and/or a change in which sources of that pollutant are regulated. States implement any necessary monitoring and measurement changes and recommend areas for attainment (meets the ambient requirements) or nonattainment (does not meet these standards). The EPA makes final attainment and nonattainment determinations. States must come up with a State Implementation Plan (SIP) to get nonattainment areas into attainment and maintain air quality in attainment areas. A company with facilities located in a nonattainment area will be most affected. Its facilities in nonattainment areas may be subject to additional data submission and emission measurement requirements during permitting renewals, its facilities may need to meet new emission limitations set by the SIP (which could result in significant capital expenditures), and it may have additional expenses and/or difficulties expanding existing facilities or building new facilities. The process, which starts with determining acceptable primary and/or secondary NAAQS and ends with executing SIPs can take years. Since the NAAQS regulations have the potential to affect both existing and new facilities, MGE continuously monitors changes to these rules to evaluate whether changes could impact its operations. In addition, the EPA has adopted interstate transport rules, such as CSAPR, to address contributions to NAAQS nonattainment from upwind sources in neighboring states. In the following paragraphs we discuss specific NAAQS and transport rule developments that may affect MGE. Ozone NAAQS In May 2021, the EPA published a final rule that expands several nonattainment areas in Wisconsin to include all of Milwaukee County wherein MGE's Elm Road Units are located. The WDNR must develop a SIP for the area, which will likely result in more stringent requirements for both constructing new development and modifying or expanding existing plants in the area. MGE will monitor the WDNR's SIP development and the extent to which the requirements will impact the Elm Road Units. At this time, MGE does not expect that the 2015 Ozone NAAQS will have a material effect on its existing plants based on final designations. EPA's Cross-State Air Pollution Rule The EPA's CSAPR and its progeny are a suite of interstate air pollution transport rules designed to reduce ozone and fine particulate (PM2.5) air levels in areas that the EPA has determined as being significantly impacted by pollution from upwind states. This is accomplished in the CSAPR through a reduction in SO 2 and NO x from qualifying fossil-fuel fired power plants in upwind "contributing" states. NO x and SO 2 contribute to fine particulate pollution and NO x contributes to ozone formation in downwind areas. Reductions are achieved through a cap and trade system. Individual plants can meet their caps through modifications and/or buying allowances on the market. MGE has met its current obligations through a combination of reduced emissions through pollution control (e.g., SCR installation at Columbia), as well as owned, received, and purchased allowances. MGE expects to meet ongoing CSAPR obligations for the foreseeable future. Clean Air Visibility Rule (CAVR) Columbia is subject to the best available retrofit technology (BART) regulations, a subsection of the EPA's CAVR, which may require pollution control retrofits. Columbia's existing pollution control upgrades, and the EPA's stance that compliance with the CSAPR equals compliance with BART, should mean that Columbia will not need to do additional work to meet BART requirements. Wisconsin's 2021 SIP argues that Wisconsin will meet its current regional haze goals based on expected emissions reductions, which include Columbia unit retirements. Given that the Wisconsin SIP recognizes the Columbia unit retirements as part of its emission reduction plan, MGE does not anticipate further obligations with this rule at Columbia. MGE will continue to monitor legal developments and any future updates to this rule. Solid Waste EPA's Coal Combustion Residuals Rule The EPA's 2015 Coal Combustion Residuals Rule (CCR) regulates coal ash from burning coal for the purpose of generating electricity as a solid waste and defines what ash use activities would be considered generally exempt beneficial reuse of coal ash. The CCR rule also regulates landfills, ash ponds, and other surface impoundments used for coal combustion residuals by regulating their design, location, monitoring, and operation. In July 2018, the EPA published a final rule that included amendments to the CCR. The amendments include the allowance of alternative performance standards for landfills and surface impoundments, revised risk-based groundwater protection standards, and an extension of the deadline by which certain facilities must cease the placement of waste in CCR units. In August 2018, the D.C. Circuit vacated parts of the 2015 CCR for not being sufficiently protective of the environment. In August 2020, the EPA revised the CCR rule to require owners or operators of coal-fired power plants to stop transporting CCR and non-CCR wastewater to unlined surface impoundments. In addition, regulated entities must initiate impoundment closure as soon as feasible and in no event later than April 2021, unless the EPA grants an extension. Columbia requested an extension to initiate closure by October 2022. The EPA has not formally approved the extension. The Columbia owners anticipate that the EPA will approve the extension request. However, we will not know the outcome of the extension request with any certainty until the EPA completes its rules review. Review of the Elm Road Units has indicated that the costs to comply with the CRR rule are not expected to be significant. Columbia's operator has completed a review of its system and has developed a compliance plan. In July 2021, the PSCW approved a CA application filed by MGE and the other owners of Columbia to install technology required to cease bottom ash transport water discharges rather than extend the longevity of the ash ponds. MGE's share of the estimated costs of the project will be approximately $ 4 million. Construction is expected to be completed by the end of 2022. b. Legal Matters - MGE Energy and MGE. MGE is involved in various legal matters that are being defended and handled in the normal course of business. MGE maintains accruals for such costs that are probable of being incurred and subject to reasonable estimation. The accrued amount for these matters is not material to the financial statements. MGE does not expect the resolution of these matters to have a material adverse effect on its consolidated results of operations, financial condition, or cash flows. Certain environmental groups have filed petitions against the PSCW regarding MGE's two most recent rate settlements. MGE has intervened in the petitions in cooperation with the PSCW. See Footnote 9.a. for more information regarding this matter. c. Purchase Contracts - MGE Energy and MGE. MGE Energy and MGE have entered into various commodity supply, transportation, and storage contracts to meet their obligations to deliver electricity and natural gas to customers. Management expects to recover these costs in future customer rates. As of December 31, 2021, the future minimum commitments related to these purchase contracts were as follows: (In thousands) 2022 2023 2024 2025 2026 Thereafter Coal (a) $ 20,662 $ 11,752 $ 4,394 $ 937 $ — $ — Natural gas Transportation and storage (b) 23,307 23,922 23,922 23,922 13,772 11,525 Supply (c) 26,987 — — — — — Purchase power (d) 14,249 5,061 5,162 5,266 5,371 5,723 Renewable energy (e) 7,999 1,185 698 714 730 25,876 Other 7,265 1,720 891 105 107 798 $ 100,469 $ 43,640 $ 35,067 $ 30,944 $ 19,980 $ 43,922 (a) Total coal commitments for the Columbia and Elm Road Units, including transportation. Fuel procurement for MGE's jointly owned Columbia and Elm Road Units is handled by WPL and WEPCO, respectively, who are the operators of those facilities. (b) MGE's natural gas transportation and storage contracts require fixed monthly payments for firm supply pipeline transportation and storage capacity. The pricing components of the fixed monthly payments for the transportation and storage contracts are approved by FERC but may be subject to change. (c) These commitments include market-based pricing. (d) MGE has several purchase power agreements to help meet future electric supply requirements. (e) Operational commitments for solar and wind facilities. d. Other Commitments. MGE Energy holds investments in nonpublic venture capital funds. From time to time, these entities require additional capital infusions from their investors. MGE Energy has committed to contribute $ 10.0 million in capital for such infusions. The timing of these infusions is dependent on the needs of the investee and is therefore uncertain at this time. In addition, MGE Energy has a three -year agreement with a venture debt fund expiring in December 2022. MGE Energy has committed to invest up to a total of $ 1.5 million into this fund. As of December 31, 2021 , MGE Energy has $ 0.7 million remaining in commitments. The timing of infusions is dependent on the needs of the fund and is therefore uncertain at this time. MGE has several other commitments related to various projects. Payments for these commitments are expected to be as follows: (In thousands) 2022 2023 2024 2025 2026 Thereafter Other commitments $ 333 $ 333 $ 333 $ 333 $ 333 $ 2,666 |
Asset Retirement Obligations
Asset Retirement Obligations | 12 Months Ended |
Dec. 31, 2021 | |
Asset Retirement Obligation Disclosure [Abstract] | |
Asset Retirement Obligations | 17. Asset Retirement Obliga tions - MGE Energy and MGE. MGE recorded an obligation for the fair value of its legal liability for asset retirement obligations (AROs) associated with removal of the West Campus Cogeneration Facility and the Elm Road Units, electric substations, combustion turbine generating units, wind generating facilities, and solar generating facilities, all of which are located on property not owned by MGE Energy and MGE and would need to be removed upon the ultimate end of the associated leases. The significant conditional AROs identified by MGE included the costs of abandoning in place gas services and mains, the abatement and disposal of equipment and buildings contaminated with asbestos and PCBs, and the proper disposal and removal of tanks, batteries, and underground cable. Changes in management's assumptions regarding settlement dates, settlement methods, or assigned probabilities could have a material effect on the liabilities and the associated regulatory asset recorded as of December 31, 2021. MGE also may have AROs relating to the removal of various assets, such as certain electric and gas distribution facilities. These facilities are generally located on property owned by third parties, on which MGE is permitted to operate by lease, permit, easement, license, or service agreement. The asset retirement obligations associated with these facilities cannot be reasonably determined due to the indeterminate life of the related agreements. The following table summarizes the change in AROs. Amounts include conditional AROs . (In thousands) 2021 2020 Balance as of January 1, $ 31,196 $ 28,355 Liabilities incurred (a) 8,589 3,503 Accretion expense 1,526 1,366 Liabilities settled ( 354 ) ( 372 ) Revisions in estimated cash flows (b) 5,623 ( 1,656 ) Balance as of December 31, $ 46,580 $ 31,196 (a) In 2021, MGE recorded an obligation of $ 4.9 million and $ 3.4 million, respectively, for the fair value of its legal liability for AROs associated with Badger Hollow I and other completed renewable projects. In 2020, MGE recorded an obligation of $ 3.2 million for the fair value of its legal liability for AROs associated with Two Creeks. See Footnote 6 for additional information on Badger Hollow I and Two Creeks . (b) In 2021, MGE revised the AROs associated with certain Columbia assets. |
Derivative and Hedging Instrume
Derivative and Hedging Instruments | 12 Months Ended |
Dec. 31, 2021 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Derivative and Hedging Instruments | 18. Derivative and Hedging Instruments - MGE Energy and MGE. a. Purpose. As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, the derivatives are recognized in the consolidated balance sheets at fair value. MGE's financial commodity derivative activities are conducted in accordance with its electric and gas risk management program, which is approved by the PSCW and limits the volume MGE can hedge with specific risk management strategies. The maximum length of time over which cash flows related to energy commodities can be hedged is four years. If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability depending on whether the derivative is in a net loss or net gain position, respectively. The deferred gain or loss is recognized in earnings in the delivery month applicable to the instrument. Gains and losses related to hedges qualifying for regulatory treatment are recoverable in gas rates through the PGA or in electric rates as a component of the fuel rules mechanism. b. Notional Amounts. The gross notional volume of open derivatives is as follows: December 31, 2021 December 31, 2020 Commodity derivative contracts 278,000 MWh 259,080 MWh Commodity derivative contracts 5,735,000 Dth 6,030,000 Dth FTRs 2,127 MW 2,869 MW PPA 250 MW 850 MW c. Financial Statement Presentation. MGE purchases and sells exchange-traded and over-the-counter options, swaps, and future contracts. These arrangements are primarily entered into to help stabilize the price risk associated with gas or power purchases. These transactions are employed by both MGE's gas and electric segments. Additionally, as a result of the firm transmission agreements that MGE holds on electricity transmission paths in the MISO market, MGE holds financial transmission rights (FTRs). An FTR is a financial instrument that entitles the holder to a stream of revenues or charges based on the differences in hourly day-ahead energy prices between two points on the transmission grid. The fair values of these instruments are offset with a corresponding regulatory asset/liability depending on whether they are in a net loss/gain position. Depending on the nature of the instrument, the gain or loss associated with these transactions will be reflected as cost of gas sold, fuel for electric generation, or purchased power expense in the delivery month applicable to the instrument. As of December 31, 2021 and December 31, 2020, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $ 2.8 million and $ 0.2 million, respectively. 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 is accounted for as a derivative contract and is recognized at its fair value on the consolidated balance sheets. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract as of December 31, 2021 and 2020, reflected a loss position of $ 2.1 million and $ 14.1 million, respectively. The actual cost will be recognized in purchased power expense in the month of purchase. The following table summarizes the fair value of the derivative instruments on the consolidated balance sheets. All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, instruments are netted with the same counterparty under a master netting agreement as well as the netting of collateral. (In thousands) Derivative Derivative Balance Sheet Location December 31, 2021 Commodity derivative contracts (a) $ 2,959 $ 811 Other current assets Commodity derivative contracts (a) 420 38 Other deferred charges FTRs 227 — Other current assets PPA N/A 2,140 Derivative liability (current) December 31, 2020 Commodity derivative contracts (b) $ 617 $ 593 Other current assets Commodity derivative contracts (b) 189 39 Other deferred charges FTRs — 23 Other current liabilities PPA N/A 10,160 Derivative liability (current) PPA N/A 3,980 Derivative liability (long-term) (a) As of December 31, 2021, MGE received collateral of $ 1.3 million from counterparties under a master netting agreement for outstanding exchange traded derivative positions. The fair value of the derivative asset disclosed in this table has not been reduced for the collateral received. (b) No collateral was posted against derivative positions as of December 31, 2020 . The following tables show the effect of netting arrangements for recognized derivative assets and liabilities that are subject to a master netting arrangement or similar arrangement on the consolidated balance sheets. Offsetting of Derivative Assets (In thousands) Gross Gross Amounts Collateral Posted Net Amount December 31, 2021 Commodity derivative contracts $ 3,379 $ ( 849 ) $ ( 1,254 ) $ 1,276 FTRs 227 — — 227 December 31, 2020 Commodity derivative contracts $ 806 $ ( 632 ) $ — $ 174 Offsetting of Derivative Liabilities (In thousands) Gross Gross Amounts Collateral Posted Net Amount December 31, 2021 Commodity derivative contracts $ 849 $ ( 849 ) $ — $ — PPA 2,140 — — 2,140 December 31, 2020 Commodity derivative contracts $ 632 $ ( 632 ) $ — $ — FTRs 23 — — 23 PPA 14,140 — — 14,140 The following tables summarize the unrealized and realized gains/losses related to the derivative instruments on the consolidated balance sheets and the consolidated statements of income. 2021 2020 Current and Other Current and Other (In thousands) Balance as of January 1, $ 13,989 $ 1,162 $ 26,875 $ 1,100 Unrealized gain ( 23,173 ) — ( 4,895 ) — Realized gain (loss) reclassified to a deferred account 2,563 ( 2,563 ) ( 2,232 ) 2,232 Realized gain (loss) reclassified to income statement 6,004 2,171 ( 5,759 ) ( 2,170 ) Balance as of December 31, $ ( 617 ) $ 770 $ 13,989 $ 1,162 Realized Losses (Gains) 2021 2020 (In thousands) Fuel for Electric Cost of Fuel for Electric Cost of Year Ended December 31: Commodity derivative contracts $ ( 3,948 ) $ ( 1,700 ) $ 2,566 $ 1,729 FTRs ( 605 ) — 63 — PPA ( 1,922 ) — 3,571 — MGE's commodity derivative contracts, FTRs, and PPA are subject to regulatory deferral. These derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. Realized gains and losses are deferred on the consolidated balance sheets and are recognized in earnings in the delivery month applicable to the instrument. As a result of the treatment described above, there are no unrealized gains or losses that flow through earnings. 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 December 31, 2021 , no collateral was required to be, or had been, posted. Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted. As of December 31, 2021 and 2020 , no counterparties were in a net liability position. Nonperformance of counterparties to the non-exchange traded derivatives could expose MGE to credit loss. However, MGE enters into transactions only with companies that meet or exceed strict credit guidelines, and it monitors these counterparties on an ongoing basis to mitigate nonperformance risk in its portfolio. As of December 31, 2021 , no counterparties had defaulted. |
Fair Value of Financial Instrum
Fair Value of Financial Instruments | 12 Months Ended |
Dec. 31, 2021 | |
Fair Value Disclosures [Abstract] | |
Fair Value of Financial Instruments | 19. Fair Value of Financial Instru ments - MGE Energy and MGE. Fair value is defined as the price that would be received to sell an asset or would be paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. The accounting standard clarifies that fair value should be based on the assumptions market participants would use when pricing the asset or liability including assumptions about risk. The standard also establishes a three level fair value hierarchy based upon the observability of the assumptions used and requires the use of observable market data when available. The levels are: Level 1 - Pricing inputs are quoted prices within active markets for identical assets or liabilities. Level 2 - Pricing inputs are quoted prices within active markets for similar assets or liabilities; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations that are correlated with or otherwise verifiable by observable market data. Level 3 - Pricing inputs are unobservable and reflect management's best estimate of what market participants would use in pricing the asset or liability. a. Fair Value of Financial Assets and Liabilities Recorded at the Carrying Amount. The carrying amount of cash, cash equivalents, and outstanding commercial paper approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of long-term debt is based on quoted market prices for similar financial instruments. Since long-term debt is not traded in an active market, it is classified as Level 2. The estimated fair market value of financial instruments are as follows: December 31, 2021 December 31, 2020 (In thousands) Carrying Amount Fair Carrying Amount Fair MGE Energy Assets: Cash and cash equivalents $ 17,438 $ 17,438 $ 44,738 $ 44,738 Liabilities: Short-term debt - commercial paper 5,500 5,500 52,500 52,500 Long-term debt (a) 623,449 729,914 528,220 639,271 MGE Assets: Cash and cash equivalents $ 6,401 $ 6,401 $ 4,103 $ 4,103 Liabilities: Short-term debt - commercial paper 5,500 5,500 52,500 52,500 Long-term debt (a) 623,449 729,914 528,220 639,271 (a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $ 4.3 million and $ 4.1 million as of December 31, 2021 and 2020 , respectively. b. Recurring Fair Value Measurements. The following table presents the balances of assets and liabilities measured at fair value on a recurring basis. Fair Value as of December 31, 2021 (In thousands) Total Level 1 Level 2 Level 3 MGE Energy Assets: Derivatives, net (b) $ 3,606 $ 1,170 $ — $ 2,436 Exchange-traded investments 1,296 1,296 — — Total Assets $ 4,902 $ 2,466 $ — $ 2,436 Liabilities: Derivatives, net (b) $ 2,989 $ 731 $ — $ 2,258 Deferred compensation 3,653 — 3,653 — Total Liabilities $ 6,642 $ 731 $ 3,653 $ 2,258 MGE Assets: Derivatives, net (b) $ 3,606 $ 1,170 $ — $ 2,436 Exchange-traded investments 230 230 — — Total Assets $ 3,836 $ 1,400 $ — $ 2,436 Liabilities: Derivatives, net (b) $ 2,989 $ 731 $ — $ 2,258 Deferred compensation 3,653 — 3,653 — Total Liabilities $ 6,642 $ 731 $ 3,653 $ 2,258 Fair Value as of December 31, 2020 (In thousands) Total Level 1 Level 2 Level 3 MGE Energy Assets: Derivatives, net (b) $ 806 $ 436 $ — $ 370 Exchange-traded investments 1,750 1,750 — — Total Assets $ 2,556 $ 2,186 $ — $ 370 Liabilities: Derivatives, net (b) $ 14,795 $ 370 $ — $ 14,425 Deferred compensation 3,509 — 3,509 — Total Liabilities $ 18,304 $ 370 $ 3,509 $ 14,425 MGE Assets: Derivatives, net (b) $ 806 $ 436 $ — $ 370 Exchange-traded investments 603 603 — — Total Assets $ 1,409 $ 1,039 $ — $ 370 Liabilities: Derivatives, net (b) $ 14,795 $ 370 $ — $ 14,425 Deferred compensation 3,509 — 3,509 — Total Liabilities $ 18,304 $ 370 $ 3,509 $ 14,425 (b) As of December 31, 2021 , MGE received collateral of $ 1.3 million from counterparties under a master netting agreement for outstanding exchange traded derivative positions. The fair value of the derivative asset disclosed in this table has not been reduced for the collateral received. No collateral was posted against derivative positions owed to counterparties under a master netting agreement on the consolidated balance sheet as of December 31, 2020 . Investments include exchange-traded investment securities valued using quoted prices on active exchanges and are therefore classified as Level 1. The deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. These amounts are included within other deferred liabilities in the consolidated balance sheets. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26 -week maturity increased by 1 % compounded monthly with a minimum annual rate of 7 %, compounded monthly. The notional investments are based upon observable market data, however, since the deferred compensation obligations themselves are not exchanged in an active market, they are classified as Level 2. Derivatives include exchange-traded derivative contracts, over-the-counter transactions, a purchased power agreement, and FTRs. Most exchange-traded derivative contracts are valued based on unadjusted quoted prices in active markets and are therefore classified as Level 1. A small number of exchange-traded derivative contracts are valued using quoted market pricing in markets with insufficient volumes and are therefore considered unobservable and classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange-traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3. The purchased power agreement (see Footnote 18) was valued using an internal pricing model and therefore is classified as Level 3. The model projects future market energy prices and compares those prices to the projected power costs to be incurred under the contract. Inputs to the model require significant management judgment and estimation. Future energy prices are based on a forward power pricing curve using exchange-traded contracts in the electric futures market. A basis adjustment is applied to the market energy price to reflect the price differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points is reviewed and a discount (below 100%) or premium (above 100%) is derived. This comparison is done for both peak times when demand is high and off peak times when demand is low. If the basis adjustment is lowered, the fair value measurement will decrease, and if the basis adjustment is increased, the fair value measurement will increase. The projected power costs anticipated to be incurred under the purchased power agreement are determined using many factors, including historical generating costs, future prices, and expected fuel mix of the counterparty. An increase in the projected fuel costs would result in a decrease in the fair value measurement of the purchased power agreement. A significant input that MGE estimates is the counterparty's fuel mix in determining the projected power cost. MGE also considers the assumptions that market participants would use in valuing the asset or liability. This consideration includes assumptions about market risk such as liquidity, volatility, and contract duration. The fair value model uses a discount rate that incorporates discounting, credit, and model risks. The following table presents the significant unobservable inputs used in the pricing model. Model Input Significant Unobservable Inputs 2021 2020 Basis adjustment: On peak 94.1 % 94.2 % Off peak 92.4 % 94.5 % Counterparty fuel mix: Internal generation - range 41 %- 66 % 46 %- 65 % Internal generation - weighted average 56.6 % 56.5 % Purchased power - range 59 %- 34 % 54 %- 35 % Purchased power - weighted average 43.4 % 43.5 % The following table summarizes the changes in Level 3 commodity derivative assets and liabilities measured at fair value on a recurring basis. (In thousands) 2021 2020 2019 Balance as of January 1, $ ( 14,055 ) $ ( 26,456 ) $ ( 32,002 ) Realized and unrealized gains (losses): Included in regulatory assets — 12,402 5,545 Included in regulatory liability 14,234 — — Included in other comprehensive income — — — Included in earnings 5,521 ( 6,439 ) ( 3,765 ) Included in current assets 237 ( 87 ) ( 70 ) Purchases 26,287 22,232 22,974 Sales — — — Issuances — — — Settlements ( 32,046 ) ( 15,707 ) ( 19,138 ) Balance as of December 31, $ 178 $ ( 14,055 ) $ ( 26,456 ) Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities held as of December 31, (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). (In thousands) Year Ended December 31, 2021 2020 2019 Purchased power expense $ 6,192 $ ( 5,888 ) $ ( 3,334 ) Cost of gas sold expense ( 671 ) ( 551 ) ( 431 ) Total $ 5,521 $ ( 6,439 ) $ ( 3,765 ) (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. |
Revenue
Revenue | 12 Months Ended |
Dec. 31, 2021 | |
Revenue from Contract with Customer [Abstract] | |
Revenue from Contract with Customer | 20. Revenue - MGE En ergy and MGE. Revenues disaggregated by revenue source were as follows: (In thousands) Year Ended December 31, Electric revenues 2021 2020 2019 Residential $ 151,646 $ 146,431 $ 140,006 Commercial 210,475 198,043 213,265 Industrial 12,529 11,514 12,772 Other-retail/municipal 35,169 32,915 35,174 Total retail 409,819 388,903 401,217 Sales to the market 9,499 4,015 5,664 Other revenues 968 774 1,404 Total electric revenues 420,286 393,692 408,285 Gas revenues Residential 110,442 88,765 95,146 Commercial/Industrial 68,895 49,682 59,051 Total retail 179,337 138,447 154,197 Gas transportation 6,185 5,713 5,293 Other revenues 98 101 385 Total gas revenues 185,620 144,261 159,875 Non-regulated energy revenues 678 680 695 Total Operating Revenue $ 606,584 $ 538,633 $ 568,855 Performance Obligations A performance obligation is a promise in a contract to transfer a distinct good or service to the customer and is the unit of account. A contract's transaction price is allocated to each distinct performance obligation and recognized as revenue when, or as, the performance obligation is satisfied. The majority of contracts have a single performance obligation. Retail Revenue (Residential, Commercial, Industrial, and Other Retail/Municipal) Providing electric and gas utility service to retail customers represents MGE's core business activity. Tariffs are approved by the PSCW through a rate order and provide MGE's customers with the standard terms and conditions, including pricing terms. The performance obligation to deliver electricity or gas is satisfied over time as the customer simultaneously receives and consumes the commodities provided by MGE. MGE recognizes revenues as the commodity is delivered to customers. Meters are read on a systematic basis throughout the month based on established meter-reading schedules and customers are subsequently billed for services received. At the end of the month, MGE accrues an estimate for unbilled commodities delivered to customers. The unbilled revenue estimate is based on daily system demand volumes, weather factors, estimated line losses, estimated customer usage by class, and applicable customer rates. Utility Cost Recovery Mechanisms MGE's tariff rates include a provision for fuel cost recovery. The PSCW allows Wisconsin utilities to defer electric fuel-related costs, less excess revenues, that fall outside a symmetrical cost tolerance band. Any over- or under-recovery of the actual costs in a given year is determined in the following year and is then reflected in future billings to electric retail customers. Over-collection of fuel-related costs that are outside the approved range will be recognized as a reduction of revenue. Under-collection of these costs will be recognized in "Purchased power" expense in the consolidated statements of income. The cumulative effects of these deferred amounts will be recorded in "Regulatory assets" or "Regulatory liabilities" on the consolidated balance sheets until they are reflected in future billings to customers. See Footnote 9.b. for further information. MGE also has other cost recovery mechanisms. For example, any over-collection of the difference between actual costs incurred and the amount of costs collected from customers is recorded as a reduction of revenue in the period incurred. Sales to the Market Sales to the market include energy charges, capacity or demand charges, and ancillary charges represented by wholesale sales of electricity made to third parties who are not ultimate users of the electricity. Most of these sales are spot market transactions on the markets operated by MISO. Each transaction is considered a performance obligation and revenue is recognized in the period in which energy charges, capacity or demand charges, and ancillary services are sold into MISO. MGE reports, on a net basis, transactions on the MISO markets in which it buys and sells power within the same hour to meet electric energy delivery requirements. Transportation of Gas MGE has contracts under which it provides gas transportation services to customers who have elected to purchase gas from a third party. MGE delivers this gas via pipelines within its service territory. Revenue is recognized as service is rendered or gas is delivered to customers. Tariffs are approved by the PSCW through a rate order and provide gas transportation customers with standard terms and conditions, including pricing terms. |
Noncontrolling Interest
Noncontrolling Interest | 12 Months Ended |
Dec. 31, 2021 | |
MGE [Member] | |
Noncontrolling Interest [Line Items] | |
Noncontrolling Interest | 21. Noncontr olling Interest - MGE. The noncontrolling interest on MGE's consolidated balance sheets was as follows: As of December 31, (In thousands) 2021 2020 MGE Power Elm Road (a) $ 101,507 $ 96,856 MGE Power West Campus (a) 47,080 44,340 Total Noncontrolling Interest $ 148,587 $ 141,196 The net income attributable to noncontrolling interest, net of tax, was as follows: Years ending December 31, (In thousands) 2021 2020 2019 MGE Power Elm Road (a) $ 15,151 $ 15,184 $ 15,153 MGE Power West Campus (a) 7,240 7,209 7,196 Net Income Attributable to Noncontrolling Interest, Net of Tax $ 22,391 $ 22,393 $ 22,349 (a) MGE Power Elm Road and MGE Power West Campus are not subsidiaries of MGE; however, they have been consolidated in the consolidated financial statements of MGE (see Footnote 3). MGE Power Elm Road and MGE Power West Campus are 100 % owned by MGE Power, and MGE Power is 100 % owned by MGE Energy. MGE Energy's proportionate share of the equity and net income (through its wholly owned subsidiary MGE Power) of MGE Power Elm Road and MGE Power West Campus is classified within the MGE consolidated financial statements as noncontrolling interest . |
Segment Information
Segment Information | 12 Months Ended |
Dec. 31, 2021 | |
Segment Reporting [Abstract] | |
Segment Information | 22. Segment Inform ation - MGE Energy and MGE. The electric utility business purchases, generates and distributes electricity, and contracts for transmission service. The gas utility business purchases and distributes natural gas and contracts for the transportation of natural gas. Both the electric and gas segments operate through MGE Energy's principal subsidiary, MGE. The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power, MGE Power Elm Road, and MGE Power West Campus. These subsidiaries own electric generating capacity that they lease to MGE to assist MGE. MGE Power Elm Road has an ownership interest in two coal-fired generating units in Oak Creek, Wisconsin, which are leased to MGE, and MGE Power West Campus owns a controlling interest in the electric generation plant of a natural gas-fired cogeneration facility on the UW campus. MGE Power West Campus's portion is also leased to MGE. The transmission investment segment invests in ATC, a company that provides electric transmission services primarily in Wisconsin, and ATC Holdco, a company formed to pursue electric transmission development and investments outside of Wisconsin. These investments are held in MGE Transco and MGEE Transco, respectively. See Footnote 7 for further discussion. The "All Others" segment includes: corporate, CWDC, MAGAEL, MGE State Energy Services, MGE Services, and North Mendota. These entities' operations consist of investing in companies and property which relate to the regulated operations, financing the regulated operations. General corporate expenses include the cost of executive management, corporate accounting and finance, information technology, risk management, human resources and legal functions, and employee benefits that are allocated to electric and gas segments based on formulas prescribed by the PSCW. Identifiable assets are those used in MGE's operations in each segment. Sales between our electric and gas segments are based on PSCW approved tariffed rates. Additionally, intersegment operations related to the leasing arrangement between our electric segment and MGE Power Elm Road/MGE Power West Campus are based on terms previously approved by the PSCW. Consistent with internal reporting, management has presented the direct financing capital leases between MGE and MGE Power Elm Road/MGE Power West Campus based on actual lease payments included in rates. Lease payments made by MGE to MGE Power Elm Road and MGE Power West Campus are shown as operating expenses. The lease payments received by MGE Power Elm Road and MGE Power West Campus from MGE are shown as lease income in interdepartmental revenues. The depreciation expense associated with the Elm Road Units and WCCF is reflected in the nonregulated energy segment. The following table shows segment information for MGE Energy's and MGE's operations: (In thousands) Electric Gas Non-Regulated Energy Transmission Investment All Others Consolidation/ Consolidated Total Year Ended December 31, 2021 Operating revenues $ 420,286 $ 185,620 $ 678 $ — $ — $ — $ 606,584 Interdepartmental revenues 556 22,728 40,866 — — ( 64,150 ) — Total operating revenues 420,842 208,348 41,544 — — ( 64,150 ) 606,584 Depreciation and amortization ( 56,672 ) ( 12,852 ) ( 7,459 ) — — — ( 76,983 ) Operating income (loss) 58,993 25,133 33,936 — ( 768 ) — 117,294 Interest (expense) income, net ( 15,261 ) ( 4,315 ) ( 4,577 ) — 41 — ( 24,112 ) Income tax (provision) benefit 10,672 ( 4,922 ) ( 7,998 ) ( 2,486 ) 619 — ( 4,115 ) Equity in earnings of investments — — — 9,339 ( 69 ) — 9,270 Net income (loss) 63,910 15,511 21,361 6,852 ( 1,873 ) — 105,761 Year Ended December 31, 2020 Operating revenues $ 393,692 $ 144,261 $ 680 $ — $ — $ — $ 538,633 Interdepartmental revenues 765 12,157 40,402 — — ( 53,324 ) — Total operating revenues 394,457 156,418 41,082 — — ( 53,324 ) 538,633 Depreciation and amortization ( 54,658 ) ( 12,049 ) ( 7,481 ) — — — ( 74,188 ) Operating income (loss) 57,847 19,674 33,460 ( 1 ) ( 983 ) — 109,997 Interest (expense) income, net ( 14,446 ) ( 4,370 ) ( 4,826 ) — 121 — ( 23,521 ) Income tax (provision) benefit ( 4,230 ) ( 4,805 ) ( 7,800 ) ( 2,786 ) 198 — ( 19,423 ) Equity in earnings of investments — — — 10,221 — — 10,221 Net income (loss) 50,522 14,167 20,834 7,434 ( 539 ) — 92,418 Year Ended December 31, 2019 Operating revenues $ 408,285 $ 159,875 $ 695 $ — $ — $ — $ 568,855 Interdepartmental revenues 806 16,070 40,020 — — ( 56,896 ) — Total operating revenues 409,091 175,945 40,715 — — ( 56,896 ) 568,855 Depreciation and amortization ( 52,755 ) ( 11,320 ) ( 7,487 ) — — — ( 71,562 ) Operating income (loss) 59,180 19,528 33,084 — ( 882 ) — 110,910 Interest (expense) income, net ( 14,978 ) ( 4,237 ) ( 5,083 ) — 1,235 — ( 23,063 ) Income tax (provision) benefit ( 5,037 ) ( 4,753 ) ( 7,628 ) ( 2,602 ) 236 — ( 19,784 ) Equity in earnings of investments — — — 9,547 — — 9,547 Net income (loss) 46,318 14,088 20,373 6,945 ( 850 ) — 86,874 (In thousands) Electric Gas Non-Regulated Energy Consolidation/ Elimination Entries Consolidated Total Year Ended December 31, 2021 Operating revenues $ 420,286 $ 185,620 $ 678 $ — $ 606,584 Interdepartmental revenues 556 22,728 40,866 ( 64,150 ) — Total operating revenues 420,842 208,348 41,544 ( 64,150 ) 606,584 Depreciation and amortization ( 56,672 ) ( 12,852 ) ( 7,459 ) — ( 76,983 ) Operating income 58,993 25,133 33,936 — 118,062 Interest expense, net ( 15,261 ) ( 4,315 ) ( 4,577 ) — ( 24,153 ) Income tax provision 10,672 ( 4,922 ) ( 7,998 ) — ( 2,248 ) Net income attributable to MGE 63,910 15,511 21,361 ( 22,391 ) 78,391 Year Ended December 31, 2020 Operating revenues $ 393,692 $ 144,261 $ 680 $ — $ 538,633 Interdepartmental revenues 765 12,157 40,402 ( 53,324 ) — Total operating revenues 394,457 156,418 41,082 ( 53,324 ) 538,633 Depreciation and amortization ( 54,658 ) ( 12,049 ) ( 7,481 ) — ( 74,188 ) Operating income 57,847 19,674 33,460 — 110,981 Interest expense, net ( 14,446 ) ( 4,370 ) ( 4,826 ) — ( 23,642 ) Income tax provision ( 4,230 ) ( 4,805 ) ( 7,800 ) — ( 16,835 ) Net income attributable to MGE 50,522 14,167 20,834 ( 22,393 ) 63,130 Year Ended December 31, 2019 Operating revenues $ 408,285 $ 159,875 $ 695 $ — $ 568,855 Interdepartmental revenues 806 16,070 40,020 ( 56,896 ) — Total operating revenues 409,091 175,945 40,715 ( 56,896 ) 568,855 Depreciation and amortization ( 52,755 ) ( 11,320 ) ( 7,487 ) — ( 71,562 ) Operating income 59,180 19,528 33,084 — 111,792 Interest expense, net ( 14,978 ) ( 4,237 ) ( 5,083 ) — ( 24,298 ) Income tax provision ( 5,037 ) ( 4,753 ) ( 7,628 ) — ( 17,418 ) Net income attributable to MGE 46,318 14,088 20,373 ( 22,349 ) 58,430 The following table shows segment information for MGE Energy's and MGE's assets and capital expenditures: Utility Consolidated (In thousands) MGE Energy Electric Gas Non-regulated Energy Transmission Investment (a) All Others Consolidation/ Elimination Entries Total Assets: December 31, 2021 $ 1,525,163 $ 485,345 $ 252,584 $ 75,990 $ 467,954 $ ( 435,130 ) $ 2,371,906 December 31, 2020 1,421,302 444,702 254,298 74,480 495,483 ( 436,614 ) 2,253,651 December 31, 2019 1,308,277 408,001 258,004 71,668 443,278 ( 407,564 ) 2,081,664 Capital Expenditures: Year ended Dec. 31, 2021 $ 115,234 $ 34,071 $ 3,864 $ — $ — $ — $ 153,169 Year ended Dec. 31, 2020 162,210 36,906 4,023 — — — 203,139 Year ended Dec. 31, 2019 125,086 36,193 2,757 — — — 164,036 Utility Consolidated (In thousands) Electric Gas Non-regulated Energy Consolidation/ Elimination Entries Total Assets: December 31, 2021 $ 1,525,163 $ 485,345 $ 252,534 $ ( 267 ) $ 2,262,775 December 31, 2020 1,421,302 444,702 254,248 ( 281 ) 2,119,971 December 31, 2019 1,308,277 408,001 257,954 ( 755 ) 1,973,477 Capital Expenditures: Year ended Dec. 31, 2021 $ 115,234 $ 34,071 $ 3,864 $ — $ 153,169 Year ended Dec. 31, 2020 162,210 36,906 4,023 — 203,139 Year ended Dec. 31, 2019 125,086 36,193 2,757 — 164,036 (a) The Transmission Investment segment represents MGE Energy's investment in equity method investees. |
Condensed Parent Company Financ
Condensed Parent Company Financial Statements | 12 Months Ended |
Dec. 31, 2021 | |
Condensed Financial Information of Parent Company Only Disclosure [Abstract] | |
Condensed Parent Company Financial Statements | Schedule I Condensed Parent Company Financial Statements MGE Energy, Inc. Statements of Income (Parent Company Only) (In thousands) For the Years Ended December 31, 2021 2020 2019 Operating Expenses: Other operations and maintenance $ 711 $ 882 $ 815 Total Operating Expenses 711 882 815 Operating Loss ( 711 ) ( 882 ) ( 815 ) Equity in earnings of investments 107,883 92,922 87,728 Other income (loss), net ( 2,163 ) 94 ( 1,500 ) Interest income, net 5 78 1,224 Income before income taxes 105,014 92,212 86,637 Income tax provision 747 206 237 Net Income $ 105,761 $ 92,418 $ 86,874 The accompanying notes are an integral part of the above consolidated financial statements. MGE Energy, Inc. Statements of Cash Flows (Parent Company Only) (In thousands) For the Years Ended December 31, 2021 2020 2019 Net Cash Flows Provided by Operating Activities $ 27,535 $ 27,631 $ 27,901 Investing Activities: Contributions to affiliates — ( 32,157 ) ( 33,631 ) Contributions to other investments ( 4,006 ) ( 3,809 ) ( 4,496 ) Other 843 622 214 Cash Used for Investing Activities ( 3,163 ) ( 35,344 ) ( 37,913 ) Financing Activities: Issuance of common stock, net — 79,635 — Cash dividends paid on common stock ( 54,788 ) ( 51,729 ) ( 47,842 ) Cash Provided by (Used for) Financing Activities ( 54,788 ) 27,906 ( 47,842 ) Change in cash, cash equivalents, and restricted cash ( 30,416 ) 20,193 ( 57,854 ) Cash, cash equivalents, and restricted cash at beginning of period 37,375 17,182 75,036 Cash, cash equivalents, and restricted cash at end of period $ 6,959 $ 37,375 $ 17,182 The accompanying notes are an integral part of the above consolidated financial statements. Schedule I Condensed Parent Company Financial Statements (continued) MGE Energy, Inc. Balance Sheets (Parent Company Only) (In thousands) As of December 31, ASSETS 2021 2020 Current Assets: Cash and cash equivalents $ 6,959 $ 37,375 Other current assets 1,681 1,494 Total Current Assets 8,640 38,869 Other deferred assets and other 244 364 Investments: Investments in affiliates 1,036,347 953,810 Other investments 18,927 15,634 Total Investments 1,055,274 969,444 Total Assets $ 1,064,158 $ 1,008,677 LIABILITIES AND SHAREHOLDERS' EQUITY Current Liabilities: Accounts payable to affiliates $ 548 $ 530 Other current liabilities 2,516 66 Total Current Liabilities 3,064 596 Other Credits: Deferred income taxes 32,014 29,926 Accounts payable to affiliates 1,589 2,118 Other deferred liabilities 23 37 Total Other Credits 33,626 32,081 Shareholders' Equity: Common shareholders' equity 431,066 430,571 Retained earnings 596,402 545,429 Total Shareholders' Equity 1,027,468 976,000 Commitments and contingencies (see Footnote 3) Total Liabilities and Shareholders' Equity $ 1,064,158 $ 1,008,677 The accompanying notes are an integral part of the above consolidated financial statements. Schedule I Condensed Parent Company Financial Statements (continued) Notes to Condensed Financial Statements (Parent Company Only) 1. Basis of Presentation. MGE Energy is a holding company and conducts substantially all of its business operations through its subsidiaries. For Parent Company only presentation, investment in subsidiaries are accounted for using the equity method. These condensed Parent Company financial statements and related notes have been prepared in accordance with Rule 12-04, Schedule I of Regulation S-X. These statements should be read in conjunction with the financial statements and the notes in Item 8. Financial Statements and Supplementary Data of the Annual Report on Form 10-K for the year ended December 31, 2021. 2. Credit Agreements. As of December 31, 2021 , MGE Energy had access to an unsecured, committed credit facility with aggregate bank commitments of $ 50.0 million. As of December 31, 2021 , no borrowings were outstanding under this facility. See Footnote 13 of the Notes to Consolidated Financial Statements in this Report for further information regarding MGE Energy's credit agreement. 3. Commitments and Contingencies. See Footnote 16 of the Notes to Consolidated Financial Statements in this Report for information regarding commitments and contingencies. 4. Dividends from Affiliates. Dividends from Affiliates (In thousands) 2021 2020 2019 MGE $ 5,000 $ — $ — MGE Power Elm Road 10,500 15,500 15,500 MGE Power West Campus 4,500 6,000 8,000 MGE Transco 5,464 5,864 4,653 MGEE Transco — 350 93 Total $ 25,464 $ 27,714 $ 28,246 Dividend Restrictions Dividend payments by MGE to MGE Energy are subject to restrictions arising under a PSCW rate order and, to a lesser degree, MGE's first mortgage bonds. The PSCW order restricts any dividends that MGE may pay MGE Energy if its common equity ratio, calculated in the manner used in the rate proceeding, is less than 55 %. MGE's thirteen month rolling average common equity ratio as of December 31, 2021, is 60.7 % as determined under the calculation used in the rate proceeding. This restriction did not impact MGE's payment of dividends in 2021. Cash dividends of $ 5.0 million were paid by MGE to MGE Energy in 2021 . No cash dividends were paid by MGE to MGE Energy in 2020. The rate proceeding calculation includes as indebtedness imputed amounts for MGE's outstanding purchase power capacity payments and other PSCW adjustments but does not include the indebtedness associated with MGE Power Elm Road or MGE Power West Campus, which are consolidated into MGE's financial statements but are not direct obligations of MGE. MGE has covenanted with the holders of its first mortgage bonds not to declare or pay any dividend or make any other distribution on or purchase any shares of its common stock unless, after giving effect thereto, the aggregate amount of all such dividends and distributions and all amounts applied to such purchases, after December 31, 1945, shall not exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2021, approximately $ 604.3 million was available for the payment of dividends under this covenant. See Footnotes 13 and 14 of the Notes to Consolidated Financial Statements in this Report for more information on dividend restrictions appearing in credit agreements and long-term debt, respectively. |
Valuation and Qualifying Accoun
Valuation and Qualifying Accounts | 12 Months Ended |
Dec. 31, 2021 | |
Valuation and Qualifying Accounts [Abstract] | |
Valuation and Qualifying Accounts | Schedule II MGE Energy, Inc. and Madison Gas and Electric Company Valuation and Qualifying Accounts Additions Balance at Charged to Charged to Net (a) Balance at Fiscal Year 2019: Accumulated provision for uncollectibles $ 3,153,662 1,614,943 20,160 ( 1,530,496 ) $ 3,258,269 Fiscal Year 2020: Accumulated provision for uncollectibles $ 3,258,269 5,164,943 (b) 26,400 ( 1,373,047 ) $ 7,076,565 Fiscal Year 2021: Accumulated provision for uncollectibles $ 7,076,565 3,402,468 (b) 32,400 ( 2,207,732 ) $ 8,303,701 (a) Net of recovery of amounts previously written off (b) During the year ended December 31, 2021 and 2020 , MGE deferred $ 1.8 million and $ 3.8 million, respectively, of bad debt expense as a regulatory asset. See Footnote 8 of the Notes to Consolidated Financial Statements in this Report for further information. |
Significant Accounting Policies
Significant Accounting Policies (Policies) | 12 Months Ended |
Dec. 31, 2021 | |
Accounting Policies [Abstract] | |
Basis of Presentation | a. Basis of Presentation - MGE Energy and MGE. The consolidated financial statements are prepared in conformity with accounting principles generally accepted in the United States of America (GAAP), which give recognition to the rate making accounting policies for regulated operations prescribed by the regulatory authorities having jurisdiction, principally the PSCW and FERC. MGE's accounting records conform to the FERC uniform system of accounts. |
Principles of Consolidation | b. Principles of Consolidation - MGE Energy and MGE. MGE, a wholly owned subsidiary of MGE Energy, is a regulated electric and gas utility headquartered in Madison, Wisconsin. MGE Energy and MGE consolidate all majority owned subsidiaries in which they have a controlling influence. Additional wholly owned subsidiaries of MGE Energy include CWDC, MAGAEL, MGE Power, MGE State Energy Services, MGE Services, MGE Transco, and MGEE Transco. CWDC owns 100 % of North Mendota, a subsidiary created to serve as a development entity for property. MGE Power owns 100 % of MGE Power Elm Road and MGE Power West Campus. MGE Power and its subsidiaries are part of MGE Energy's nonregulated energy operations, which were formed to own and lease electric generation projects to assist MGE. MGE Transco and MGEE Transco are nonregulated entities formed to own the investments in ATC and ATC Holdco, respectively. MGE did not own any subsidiaries as of December 31, 2021. MGE Energy and MGE consolidate variable interest entities (VIEs) for which it is the primary beneficiary. Variable interest entities are legal entities that possess any of the following characteristics: equity investors who have an insufficient amount of equity at risk to finance their activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or equity holders who do not receive expected losses or returns significant to the VIE. If MGE Energy or MGE is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, all relevant facts and circumstances are considered, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. Ongoing reassessments of all VIEs are performed to determine if the primary beneficiary status has changed. MGE has consolidated MGE Power Elm Road and MGE Power West Campus. Both entities are VIEs. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. See Footnote 3 for more discussion of these entities. The consolidated financial statements reflect the application of certain accounting policies described in this note. All intercompany accounts and transactions have been eliminated in consolidation. |
Use of Estimates | c. Use of Estimates - MGE Energy and MGE. In order to prepare consolidated financial statements in conformity with GAAP, management must make estimates and assumptions. These estimates could affect reported amounts of assets, liabilities, and disclosures at the date of the financial statements, as well as the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from management's estimates. MGE Energy and MGE continues to assess the presence of COVID-19 developments and its impact on the assumptions and estimates used in the preparation of these financial statements. |
Cash Equivalents | Cash Equivalents All highly liquid investments purchased with an original maturity of three months or less are considered to be cash equivalents. |
Restricted Cash | Restricted Cash MGE has certain cash accounts that are restricted to uses other than current operations and designated for a specific purpose. MGE's restricted cash accounts include cash held by trustees for certain employee benefits and cash deposits held by third parties. These are included in "Other current assets" on the consolidated balance sheets. |
Receivable Margin Account | Receivable – Margin Account Cash amounts held by counterparties as margin collateral for certain financial transactions are recorded as Receivable – margin account in "Other current assets" on the consolidated balance sheets. The costs being hedged are fuel for electric generation, purchased power, and cost of gas sold. |
Trade Receivables, Allowance for Doubtful Accounts, and Concentration Risk | e. Trade Receivables, Allowance for Doubtful Accounts, and Concentration Risk - MGE Energy and MGE. Trade accounts receivable are recorded at the invoiced amount and do not bear interest. A 1 % late payment charge is recorded on all receivables unpaid after the due date. The allowance for credit losses associated with these receivables represents MGE's best estimate of the amount of probable credit losses for existing accounts receivable. MGE manages concentration of credit risk through its credit and collection policies, which are consistent with state regulatory requirements. The allowance for credit losses is estimated based on historical write-off experience, regional economic data, review of the accounts receivable aging, and reasonable and supportable forecasts that affect the collectability of the reported amount. MGE has considered the effects of COVID-19 developments in its estimate of allowance for credit losses. As of December 31, 2021 and 2020, MGE had a reserve balance of $ 8.3 million and $ 7.1 million, respectively, against accounts receivable. During the years ended December 31, 2021 and 2020, MGE recorded $ 2.2 million and $ 1.4 million, respectively, in write-offs. During the years ended December 31, 2021 and 2020, MGE recorded $ 3.4 million and $ 5.2 million, respectively, of additional reserves. The current accounting treatment for bad debt expense allows MGE to defer any differential between bad debt expense reflected in rates and actual costs incurred in its next rate case filing. See Footnote 8 for further details of deferred bad debt expense. |
Inventories | f. Inventories - MGE Energy and MGE. Inventories consist of natural gas in storage, fuel for electric generation, materials and supplies, and renewable energy credits (RECs). MGE values natural gas in storage, fuel for electric generation, and materials and supplies using average cost. REC allowances are included in "Materials and supplies" on the consolidated balance sheets and are recorded based on specific identification. These allowances are charged to purchase power expense as they are used in operations. MGE's REC allowance balance as of December 31, 2021 and 2020, was $ 1.0 million and $ 0.8 million, respectively. |
Derivative and Hedging Instruments | g. D erivative and Hedging Instruments - MGE Energy and MGE. As part of regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices. MGE recognizes derivatives, excluding those that qualify for the normal purchases or normal sales exclusion, in the consolidated balance sheets at fair value, with changes in the fair value of derivative instruments to be recorded in current earnings or deferred in accumulated other comprehensive income (loss), depending on whether a derivative is designated as, and is effective as, a hedge and on the type of hedge transaction. Derivative activities are in accordance with the company's risk management policy. If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability depending on whether the derivative is in a net loss or net gain position, respectively. Cash flows from such derivative instruments are classified on a basis consistent with the nature of the underlying hedged item. |
Regulatory Assets and Liabilities | h. Regulatory Assets and Liabilities - MGE Energy and MGE. Regulatory assets and regulatory liabilities are recorded consistent with regulatory treatment. Regulatory assets represent costs which are deferred due to the probable future recovery from customers through regulated rates. Regulatory liabilities represent the excess recovery of costs or accrued credits which were deferred because MGE believes it is probable such amounts will be returned to customers through future regulated rates. Regulatory assets and liabilities are amortized in the consolidated statements of income consistent with the recovery or refund included in customer rates. MGE believes it is probable that its recorded regulatory assets and liabilities will be recovered and refunded, respectively, in future rates. See Footnote 8 for further information. |
Debt Issuance Costs | i. Debt Issuance Costs - MGE Energy and MGE. Premiums, discounts, and expenses incurred with the issuance of outstanding long-term debt are amortized over the life of the debt issue. Any call premiums or unamortized expenses associated with refinancing higher-cost debt obligations used to finance utility-regulated assets and operations are amortized consistent with regulatory treatment of those items. These costs are included as a direct reduction to the related debt liability on the consolidated balance sheets. |
Property, Plant, and Equipment | j. Property, Plant, and Equipment - MGE Energy and MGE. Property, plant, and equipment is recorded at original cost. Cost includes indirect costs consisting of payroll taxes, pensions, postretirement benefits, other fringe benefits, and administrative and general costs. Also, included in the cost is AFUDC for utility property and capitalized interest for nonregulated property. Additions for significant replacements of property are charged to property, plant, and equipment at cost; and minor items are charged to maintenance expense. Depreciation rates on utility property are approved by the PSCW, based on the estimated economic lives of property, and include estimates for salvage value and removal costs. Removal costs of utility property, less any salvage value, are adjusted through regulatory liabilities. Depreciation rates on nonregulated property are based on the estimated economic lives of the property. See Footnote 4 for further information. Provisions at composite straight-line depreciation rates approximate the following percentages for the cost of depreciable property: 2021 2020 2019 Electric 3.2 % 3.5 % 3.6 % Gas 2.2 % 2.2 % 2.1 % Nonregulated 2.4 % 2.3 % 2.3 % |
Asset Retirement Obligations | k. Asset Retirement Obligations - MGE Energy and MGE. A liability is recorded for the fair value of an asset retirement obligation (ARO) to be recognized in the period in which it is incurred if it can be reasonably estimated. The offsetting associated asset retirement costs are capitalized as a long-lived asset and depreciated over the asset's useful life. The expected present value technique used to calculate the fair value of ARO liabilities includes assumptions about costs, probabilities, settlement dates, interest accretion, and inflation. Revisions to the assumptions, including the timing or amount of expected asset retirement costs, could result in increases or decreases to the AROs. All asset retirement obligations are recorded as "Other long-term liabilities" on the consolidated balance sheets. MGE has regulatory treatment and recognizes regulatory assets or liabilities for the timing differences between when it recovers legal AROs in rates and when it would recognize these costs. See Footnote 17 for further information. |
Repairs and Maintenance Expense | l. Repairs and Maintenance Expense - MGE Energy and MGE. MGE utilizes the direct expensing method for planned major maintenance projects. Under this method, MGE expenses all costs associated with major planned maintenance activities as incurred. |
Purchased Gas Adjustment Clause | m. Purchased Gas Adjustment Clause - MGE Energy and MGE. MGE's natural gas rates are subject to a fuel adjustment clause designed to recover or refund the difference between the actual cost of purchased gas and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates. As of December 31, 2021 and 2020, MGE had over collected $ 1.4 million and $ 1.8 million, respectively. These amounts are included in "Regulatory liabilities – current" on the consolidated balance sheets. |
Revenue Recognition | n. Revenue Recognition - MGE Energy and MGE. Operating revenues are recorded as service is rendered or energy is delivered to customers. Meters are read on a systematic basis throughout the month based on established meter-reading schedules. At the end of the month, MGE accrues an estimate for the unbilled amount of energy delivered to customers. The unbilled revenue estimate is based on daily system demand volumes, weather factors, estimated line losses, estimated customer usage by class, and applicable customer rates. See Footnote 20 for further information. Performance Obligations A performance obligation is a promise in a contract to transfer a distinct good or service to the customer and is the unit of account. A contract's transaction price is allocated to each distinct performance obligation and recognized as revenue when, or as, the performance obligation is satisfied. The majority of contracts have a single performance obligation. Retail Revenue (Residential, Commercial, Industrial, and Other Retail/Municipal) Providing electric and gas utility service to retail customers represents MGE's core business activity. Tariffs are approved by the PSCW through a rate order and provide MGE's customers with the standard terms and conditions, including pricing terms. The performance obligation to deliver electricity or gas is satisfied over time as the customer simultaneously receives and consumes the commodities provided by MGE. MGE recognizes revenues as the commodity is delivered to customers. Meters are read on a systematic basis throughout the month based on established meter-reading schedules and customers are subsequently billed for services received. At the end of the month, MGE accrues an estimate for unbilled commodities delivered to customers. The unbilled revenue estimate is based on daily system demand volumes, weather factors, estimated line losses, estimated customer usage by class, and applicable customer rates. Utility Cost Recovery Mechanisms MGE's tariff rates include a provision for fuel cost recovery. The PSCW allows Wisconsin utilities to defer electric fuel-related costs, less excess revenues, that fall outside a symmetrical cost tolerance band. Any over- or under-recovery of the actual costs in a given year is determined in the following year and is then reflected in future billings to electric retail customers. Over-collection of fuel-related costs that are outside the approved range will be recognized as a reduction of revenue. Under-collection of these costs will be recognized in "Purchased power" expense in the consolidated statements of income. The cumulative effects of these deferred amounts will be recorded in "Regulatory assets" or "Regulatory liabilities" on the consolidated balance sheets until they are reflected in future billings to customers. See Footnote 9.b. for further information. MGE also has other cost recovery mechanisms. For example, any over-collection of the difference between actual costs incurred and the amount of costs collected from customers is recorded as a reduction of revenue in the period incurred. Sales to the Market Sales to the market include energy charges, capacity or demand charges, and ancillary charges represented by wholesale sales of electricity made to third parties who are not ultimate users of the electricity. Most of these sales are spot market transactions on the markets operated by MISO. Each transaction is considered a performance obligation and revenue is recognized in the period in which energy charges, capacity or demand charges, and ancillary services are sold into MISO. MGE reports, on a net basis, transactions on the MISO markets in which it buys and sells power within the same hour to meet electric energy delivery requirements. Transportation of Gas MGE has contracts under which it provides gas transportation services to customers who have elected to purchase gas from a third party. MGE delivers this gas via pipelines within its service territory. Revenue is recognized as service is rendered or gas is delivered to customers. Tariffs are approved by the PSCW through a rate order and provide gas transportation customers with standard terms and conditions, including pricing terms. |
Utility Cost Recovery | o. Utility Cost Recovery - MGE Energy and MGE. MGE's tariff rates include a provision for fuel cost recovery. The PSCW allows Wisconsin utilities to defer electric fuel-related costs, less excess revenues, that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its annual fuel proceedings. Any over- or under-recovery of the actual costs in a given year is determined in the following year and is then reflected in future billings to electric retail customers. Over-collection of fuel-related costs that are outside the approved range will be recognized as a reduction of revenue. Under-collection of these costs will be recognized in "Purchased power" expense in the consolidated statements of income. The cumulative effects of these deferred amounts will be recorded as a regulatory asset or regulatory liability until they are reflected in future billings to customers. See Footnote 9.b. for further information. |
Regional Transmission Organizations | p. Regional Transmission Organizations - MGE Energy and MGE. MGE reports on a net basis transactions on the MISO markets in which it buys and sells power within the same hour to meet electric energy delivery requirements. This treatment resulted in a $ 113.6 million, a $ 61.8 million, and a $ 75.6 million reduction to sales to the market and purchase power expense for MISO markets for the years ended December 31, 2021, 2020, and 2019 , respectively. |
Allowance for Funds Used During Construction | q. Allowance for Funds Used During Construction - MGE Energy and MGE. Allowance for funds used during construction is included in utility plant accounts and represents the cost of borrowed funds used during plant construction and a return on shareholder's capital used for construction purposes. In the consolidated income statements, the cost of borrowed funds (AFUDC-debt) is presented as an offset to "Interest expense" and the return on shareholder's capital (AFUDC-equity funds) is shown as an item within "Other income." For 2021, 2020 and 2019 , as approved by the PSCW, MGE capitalized AFUDC-debt and equity on 50 % of applicable average construction work in progress at 6.89 %, 7.03 %, and 7.00 %, respectively. MGE received specific approval to recover 100 % AFUDC on certain costs for Saratoga, Two Creeks, Badger Hollow I and II, its customer information and billing project, and on certain environmental costs for Columbia. These amounts are recovered under the ratemaking process over the service lives of the related properties. During 2021, 2020, and 2019, MGE recorded $ 1.7 million, $ 2.1 million, and $ 0.8 million, respectively, of AFUDC-debt. During 2021, 2020, and 2019, MGE recorded $ 5.0 million, $ 5.9 million, and $ 2.3 million, respectively, of AFUDC-equity. |
Investments | r. Investments - MGE Energy and MGE. Investments in limited liability companies that have specific ownership accounts in which MGE Energy or MGE's ownership interest is more than minor and are considered to have significant influence are accounted for using the equity method. For equity security investments without readily determinable fair values and for which MGE Energy and MGE do not have significant influence, MGE Energy and MGE have elected to use the practicability exception to measure these investments, defined as cost adjusted for changes from observable transactions for identical or similar investments of the same issuer, less impairment. Changes in measurement are reported in earnings. Equity security investments with readily determinable fair values are carried at fair value. Realized and unrealized gains and losses are included in earnings. See Footnote 7 for further information on investments and Footnote 19 for further information on fair value of investments. |
Capitalized Software Costs | s. Capitalized Software Costs - MGE Energy and MGE. The net book value of capitalized costs of internal use software included in property, plant, and equipment was $ 85.8 million and $ 20.4 million as of December 31, 2021 and 2020, respectively. MGE implemented a new customer information system which went live in September 2021. As of December 31, 2021 and 2020, accumulated amortization was $ 42.6 million and $ 36.9 million, respectively. During 2021, MGE recorded $ 5.7 million of amortization expense. During 2020 and 2019, MGE recorded $ 5.1 million of amortization expense. Capitalized software costs are amortized on a straight-line basis over the estimated useful lives of the assets. The useful lives range from five to fifteen years. |
Capitalized Software Assets Hosting Arrangements | t. Capitalized Software Assets – Hosting Arrangements – MGE Energy and MGE. The net book value of capitalized costs of internal use software incurred in a hosting arrangement was $ 15.6 million and $ 14.8 million as of December 31, 2021 and 2020, respectively. As of December 31, 2021 and 2020, accumulated amortization was $ 5.4 million and $ 3.2 million, respectively. Capitalized software assets for hosted arrangements and the related accumulated amortization expense are recorded in "Other deferred assets and other" on the consolidated balance sheets. During 2021, 2020, and 2019, MGE recorded $ 2.2 million, $ 1.8 million, and $ 1.4 million, respectively, of amortization expense related to software assets for hosted arrangements. These costs are recognized in "Other operations and maintenance" expense in the consolidated statements of income and are amortized on a straight-line basis over the term of the hosted contract, which includes renewable option periods. Software assets for hosted arrangements have terms ranging from three to ten years. |
Impairment of Long-Lived Assets | u. Impairment of Long-Lived Assets - MGE Energy and MGE. MGE reviews plant and equipment and other property for impairment when events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. MGE's policy for determining when long-lived assets are impaired is to recognize an impairment loss if the sum of the expected future cash flows (undiscounted and without interest charges) from an asset are less than the carrying amount of that asset. If an impairment loss is recognized, the amount that will be recorded will be measured as the amount by which the carrying amount of the asset exceeds the fair value of the asset. When it becomes probable that a generating unit will be retired before the end of its useful life, MGE assesses whether the generating unit meets the criteria for probability of abandonment. If a generating unit meets the applicable criteria to be considered probable of abandonment, MGE assesses the likelihood of recovery of the remaining net book value of that generating unit at the end of each reporting period. If it becomes probable that regulators will disallow full recovery or a return on the remaining net book value of a generating unit that is either abandoned or probable of being abandoned, an impairment loss would be required. An impairment loss would be recorded for the difference of the remaining net book value of the generating unit that is greater than the present value of the amount expected to be recovered from ratepayers. There was no impairment of long-lived assets during 2021, 2020, and 2019 . |
Income Taxes and Excise Taxes | v. Income Taxes and Excise Taxes - MGE Energy and MGE. Income taxes Under the liability method, income taxes are deferred for all temporary differences between pretax financial and taxable income and between the book and tax basis of assets and liabilities using the tax rates scheduled by law to be in effect when the temporary differences reverse. Future tax benefits are recognized to the extent that realization of such benefits is more likely than not. A valuation allowance is recorded for those benefits that do not meet this criterion. Accounting for uncertainty in income taxes applies to all tax positions and requires a recognition threshold and measurement standard for the financial statement recognition and measurement of a tax position taken, or expected to be taken, in an income tax return. The threshold is defined for recognizing tax return positions in the financial statements as "more likely than not" that the position is sustainable, based on its merits. Subsequent recognition, derecognition, and measurement is based on management's best judgment given the facts, circumstances, and information available at the reporting date. Regulatory and accounting principles have resulted in a regulatory liability related to income taxes. Excess deferred income taxes result from past taxes provided in customer rates higher than current rates. The income tax regulatory liability and deferred investment tax credit reflect the revenue requirement associated with the return of these tax benefits to customers. Investment tax credits from regulated operations are amortized over related property service lives. Excise taxes MGE Energy, through its utility operations, pays a state license fee tax in lieu of property taxes on property used in utility operations. License fee tax is calculated as a percentage of adjusted operating revenues of the prior year. The electric tax rate is 3.19 % for retail sales and 1.59 % for sales of electricity for resale by the purchaser. The tax rate on sales of natural gas is 0.97 %. The tax is required to be estimated and prepaid in the year prior to its computation and expensing. License fee tax expense, included in "Other general taxes," was $ 13.5 million, $ 14.1 million, and $ 13.9 million for the years ended December 31, 2021, 2020, and 2019, respectively. Operating income taxes, including tax credits and license fee tax, are included in rates for utility related items. |
Share-based Compensation | w. Share-Based Compensation - MGE Energy and MGE. Eligible employees and non-employee directors may receive awards of restricted stock, restricted stock units, performance units, and dividend equivalents, or any combination of the foregoing. Stock-based compensation expense is recognized on a straight-line basis over the requisite service period. Awards classified as equity awards are measured based on their grant-date fair value. Awards classified as liability awards are recorded at fair value each reporting period. Forfeitures are recognized as they occur, rather than estimating potential future forfeitures and recording them over the vesting period. |
Adoption of Accounting Principles and Recently Issued Accounting Pronouncements | |
New Accounting Pronouncements | MGE Energy and MGE reviewed FASB authoritative guidance recently issued, none of which are expected to have a material impact on the consolidated results of operations, financial condition, or cash flows. |
Leases [Abstract] | |
Leases | As part of its regular operations, MGE enters into various contracts related to IT equipment, substations, cell towers, land, wind easements, and other property in use for operations. A contract is or contains a lease if the contract conveys the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. Determination as to whether an arrangement is or contains a lease is completed at inception. Leases with an initial term of 12 months or less are not recorded on the consolidated balance sheets; lease expense for these leases are recognized on a straight-line basis over the lease term. Leases with initial terms in excess of 12 months are recorded as operating or financing leases on the consolidated balance sheets. Operating lease assets and operating lease liabilities are recognized based on the present value of the future minimum lease payments over the lease term at commencement date. For leases that do not provide an implicit rate, a collateralized incremental borrowing rate based on the information available at commencement date, including lease term, is used in determining the present value of future payments. The operating lease asset also includes any lease payments made and excludes lease incentives and initial direct costs incurred. Lease terms may include options to extend or terminate the lease when it is reasonably certain that the option will be exercised. Operating lease expense is recognized on a straight-line basis over the lease term. MGE has regulatory treatment and recognizes regulatory assets or liabilities for timing differences between when net lease costs are recorded and when costs are recognized. As of December 31, 2021 , MGE had no significant leases not yet commenced that would create significant future rights and obligations. |
Income Taxes | |
Accounting for Uncertainty in Income Taxes | The difference between the tax benefit amount taken on prior year tax returns, or expected to be taken on a current year tax return, and the tax benefit amount recognized in the financial statements is accounted for as an unrecognized tax benefit. Unrecognized tax benefits are classified with "Other deferred liabilities" on the consolidated balance sheets. The interest component recoverable in rates is offset by a regulatory asset. As of December 31, 2021, 2020, and 2019, MGE Energy and MGE have an unrecognized tax benefit primarily related to temporary tax differences associated with the change in income tax method of accounting for electric generation and electric and gas distribution repairs. In addition, as of December 31, 2019 , MGE Energy and MGE have unrecognized tax benefits relating to permanent differences and tax credits of less than $ 0.1 million. As of December 31, 2021 and 2020 , there were no unrecognized tax benefits relating to permanent differences and tax credits. The unrecognized tax benefits as of December 31, 2021 , are not expected to significantly increase or decrease within the next twelve months. In addition, statutes of limitations will expire for MGE Energy and MGE tax returns. The impact of the statutes of limitations expiring is not anticipated to be material. |
Pension Plans and Other Postretirement Benefits | |
Fair Value of Pension and Other Postretirement Benefit Plan Assets | Pension and other postretirement benefit plan investments are recorded at fair value. See Footnote 19 for more information regarding the fair value hierarchy. The following descriptions are the categories of underlying plan assets held within the pension and other postretirement benefit plans as of December 31, 2021: Cash and Cash Equivalents – This category includes highly liquid investments with maturities of less than three months which are traded in active markets. Equity Securities – These securities consist of U.S. and international stock funds. The U.S. stock funds are primarily invested in domestic equities. Securities in these funds are typically priced using the closing price from the applicable exchange, NYSE, Nasdaq, etc. The international funds are composed of international equities. Securities are priced using the closing price from the appropriate local stock exchange. Fixed Income Securities – These securities consist of U.S. bond funds and short-term funds. U.S. bond funds are priced by a pricing agent using inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. The short-term funds are valued initially at cost and adjusted for amortization of any discount or premium. Real Estate – Real estate funds are funds with a direct investment in pools of real estate properties. These funds are valued by investment managers on a periodic basis using pricing models that use independent appraisals. The fair value of real estate investments is determined using net asset value. Insurance Continuance Fund (ICF) – The ICF is a supplemental retirement plan that includes assets that have been segregated and restricted to pay retiree term life insurance premiums. Fixed Rate Fund – The Fixed Rate fund is supported by an underlying portfolio of fixed income securities, including public bonds, commercial mortgages, and private placement bonds. Public market data and GAAP reported market values are used when available to determine fair value. All of the fair values of MGE's plan assets are measured using net asset value, except for cash and cash equivalents which are considered level 1 investments. |
Common Equity | |
Common Stock | MGE Energy sells shares of its common stock through its Direct Stock Purchase and Dividend Reinvestment Plan (the Stock Plan). Those shares may be newly issued shares or shares that are purchased in the open market by an independent agent for participants in the Stock Plan. The volume and timing of share repurchases in the open market depends upon the level of dividend reinvestment and optional share purchases made by plan participants. As a result, there is no specific maximum number of shares to be repurchased and no specified termination date for the repurchases. All sales under the Stock Plan are covered by a shelf registration statement that MGE Energy filed with the SEC. |
Derivative and Hedging Instruments | |
Derivative Hedging | As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, the derivatives are recognized in the consolidated balance sheets at fair value. MGE's financial commodity derivative activities are conducted in accordance with its electric and gas risk management program, which is approved by the PSCW and limits the volume MGE can hedge with specific risk management strategies. The maximum length of time over which cash flows related to energy commodities can be hedged is four years. If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability depending on whether the derivative is in a net loss or net gain position, respectively. The deferred gain or loss is recognized in earnings in the delivery month applicable to the instrument. Gains and losses related to hedges qualifying for regulatory treatment are recoverable in gas rates through the PGA or in electric rates as a component of the fuel rules mechanism. |
Derivative Netting | All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, instruments are netted with the same counterparty under a master netting agreement as well as the netting of collateral. |
Fair Value of Financial Instruments | |
Recurring Fair Value Measurements | Fair value is defined as the price that would be received to sell an asset or would be paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. The accounting standard clarifies that fair value should be based on the assumptions market participants would use when pricing the asset or liability including assumptions about risk. The standard also establishes a three level fair value hierarchy based upon the observability of the assumptions used and requires the use of observable market data when available. The levels are: Level 1 - Pricing inputs are quoted prices within active markets for identical assets or liabilities. Level 2 - Pricing inputs are quoted prices within active markets for similar assets or liabilities; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations that are correlated with or otherwise verifiable by observable market data. Level 3 - Pricing inputs are unobservable and reflect management's best estimate of what market participants would use in pricing the asset or liability. The carrying amount of cash, cash equivalents, and outstanding commercial paper approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of long-term debt is based on quoted market prices for similar financial instruments. Since long-term debt is not traded in an active market, it is classified as Level 2. Investments include exchange-traded investment securities valued using quoted prices on active exchanges and are therefore classified as Level 1. The deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. These amounts are included within other deferred liabilities in the consolidated balance sheets. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26 -week maturity increased by 1 % compounded monthly with a minimum annual rate of 7 %, compounded monthly. The notional investments are based upon observable market data, however, since the deferred compensation obligations themselves are not exchanged in an active market, they are classified as Level 2. Derivatives include exchange-traded derivative contracts, over-the-counter transactions, a purchased power agreement, and FTRs. Most exchange-traded derivative contracts are valued based on unadjusted quoted prices in active markets and are therefore classified as Level 1. A small number of exchange-traded derivative contracts are valued using quoted market pricing in markets with insufficient volumes and are therefore considered unobservable and classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange-traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3. The purchased power agreement (see Footnote 18) was valued using an internal pricing model and therefore is classified as Level 3. The model projects future market energy prices and compares those prices to the projected power costs to be incurred under the contract. Inputs to the model require significant management judgment and estimation. Future energy prices are based on a forward power pricing curve using exchange-traded contracts in the electric futures market. A basis adjustment is applied to the market energy price to reflect the price differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points is reviewed and a discount (below 100%) or premium (above 100%) is derived. This comparison is done for both peak times when demand is high and off peak times when demand is low. If the basis adjustment is lowered, the fair value measurement will decrease, and if the basis adjustment is increased, the fair value measurement will increase. The projected power costs anticipated to be incurred under the purchased power agreement are determined using many factors, including historical generating costs, future prices, and expected fuel mix of the counterparty. An increase in the projected fuel costs would result in a decrease in the fair value measurement of the purchased power agreement. A significant input that MGE estimates is the counterparty's fuel mix in determining the projected power cost. MGE also considers the assumptions that market participants would use in valuing the asset or liability. This consideration includes assumptions about market risk such as liquidity, volatility, and contract duration. The fair value model uses a discount rate that incorporates discounting, credit, and model risks. The following table presents the significant unobservable inputs used in the pricing model. Model Input Significant Unobservable Inputs 2021 2020 Basis adjustment: On peak 94.1 % 94.2 % Off peak 92.4 % 94.5 % Counterparty fuel mix: Internal generation - range 41 %- 66 % 46 %- 65 % Internal generation - weighted average 56.6 % 56.5 % Purchased power - range 59 %- 34 % 54 %- 35 % Purchased power - weighted average 43.4 % 43.5 % |
Segment Information | |
Segment Information | The electric utility business purchases, generates and distributes electricity, and contracts for transmission service. The gas utility business purchases and distributes natural gas and contracts for the transportation of natural gas. Both the electric and gas segments operate through MGE Energy's principal subsidiary, MGE. The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power, MGE Power Elm Road, and MGE Power West Campus. These subsidiaries own electric generating capacity that they lease to MGE to assist MGE. MGE Power Elm Road has an ownership interest in two coal-fired generating units in Oak Creek, Wisconsin, which are leased to MGE, and MGE Power West Campus owns a controlling interest in the electric generation plant of a natural gas-fired cogeneration facility on the UW campus. MGE Power West Campus's portion is also leased to MGE. The transmission investment segment invests in ATC, a company that provides electric transmission services primarily in Wisconsin, and ATC Holdco, a company formed to pursue electric transmission development and investments outside of Wisconsin. These investments are held in MGE Transco and MGEE Transco, respectively. See Footnote 7 for further discussion. The "All Others" segment includes: corporate, CWDC, MAGAEL, MGE State Energy Services, MGE Services, and North Mendota. These entities' operations consist of investing in companies and property which relate to the regulated operations, financing the regulated operations. General corporate expenses include the cost of executive management, corporate accounting and finance, information technology, risk management, human resources and legal functions, and employee benefits that are allocated to electric and gas segments based on formulas prescribed by the PSCW. Identifiable assets are those used in MGE's operations in each segment. Sales between our electric and gas segments are based on PSCW approved tariffed rates. Additionally, intersegment operations related to the leasing arrangement between our electric segment and MGE Power Elm Road/MGE Power West Campus are based on terms previously approved by the PSCW. Consistent with internal reporting, management has presented the direct financing capital leases between MGE and MGE Power Elm Road/MGE Power West Campus based on actual lease payments included in rates. Lease payments made by MGE to MGE Power Elm Road and MGE Power West Campus are shown as operating expenses. The lease payments received by MGE Power Elm Road and MGE Power West Campus from MGE are shown as lease income in interdepartmental revenues. The depreciation expense associated with the Elm Road Units and WCCF is reflected in the nonregulated energy segment. |
Summary of Significant Accoun_2
Summary of Significant Accounting Policies (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Accounting Policies [Abstract] | |
Cash, Cash Equivalents, and Restricted Cash | The following table presents the components of total cash, cash equivalents, and restricted cash on the consolidated balance sheets. (In thousands) MGE Energy MGE As of December 31, 2021 2020 2021 2020 Cash and cash equivalents $ 17,438 $ 44,738 $ 6,401 $ 4,103 Restricted cash 847 644 847 644 Receivable - margin account 550 1,657 550 1,657 Cash, cash equivalents, and restricted cash $ 18,835 $ 47,039 $ 7,798 $ 6,404 |
Straight-Line Depreciation Rates | Provisions at composite straight-line depreciation rates approximate the following percentages for the cost of depreciable property: 2021 2020 2019 Electric 3.2 % 3.5 % 3.6 % Gas 2.2 % 2.2 % 2.1 % Nonregulated 2.4 % 2.3 % 2.3 % |
Variable Interest Entities (Tab
Variable Interest Entities (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Variable Interest Entity [Line Items] | |
Variable interest entities significant balance sheet accounts | MGE has included the following significant accounts on its consolidated balance sheets related to its interest in these VIEs as of December 31: MGE Power Elm Road MGE Power West Campus (In thousands) 2021 2020 2021 2020 Property, plant, and equipment, net $ 163,325 $ 166,883 $ 79,183 $ 79,077 Construction work in progress 898 697 493 677 Affiliate receivables — — 2,211 2,803 Accrued interest and accrued (prepaid) taxes 37 2,701 ( 75 ) 671 Deferred income taxes 30,696 30,646 14,726 14,521 Long-term debt (a) 48,968 51,590 35,563 37,652 Noncontrolling interest 101,507 96,856 47,080 44,340 (a) MGE Power Elm Road's long-term debt includes debt issuance costs of $ 0.3 million and $ 0.4 million as of December 31, 2021 and 2020, respectively. The debt is secured by a collateral assignment of lease payments that MGE makes to MGE Power Elm Road for use of the Elm Road Units pursuant to the related long-term leases. MGE Power West Campus's long-term debt includes debt issuance costs of $ 0.1 million as of December 31, 2021 and 2020 . The debt is secured by a collateral assignment of lease payments that MGE makes to MGE Power West Campus for use of the cogeneration facility pursuant to the long-term lease. See Footnote 14 for further information on the long-term debt securities . |
Property, Plant, and Equipment
Property, Plant, and Equipment (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Property, Plant and Equipment [Abstract] | |
Schedule of Property, Plant, and Equipment | Property, plant, and equipment consisted of the following as of December 31: MGE Energy MGE (In thousands) 2021 2020 2021 2020 Utility: Electric (a)(b) $ 1,516,533 $ 1,608,658 $ 1,516,550 $ 1,608,675 Plant anticipated to be retired early (a) 158,983 — 158,983 — Gas 546,390 496,450 546,401 496,461 Utility property, plant, and equipment, gross 2,221,906 2,105,108 2,221,934 2,105,136 Less: Accumulated depreciation and amortization (a) 636,804 721,382 636,804 721,382 Utility property, plant, and equipment, net 1,585,102 1,383,726 1,585,130 1,383,754 Nonregulated: Nonregulated 317,881 320,691 317,881 320,691 Less: Accumulated depreciation and amortization 74,812 74,131 74,812 74,131 Nonregulated property, plant, and equipment, net 243,069 246,560 243,069 246,560 Construction work in progress: Utility construction work in progress (b) 49,211 137,725 49,211 137,725 Nonregulated construction work in progress 1,392 1,374 1,392 1,374 Total property, plant, and equipment $ 1,878,774 $ 1,769,385 $ 1,878,802 $ 1,769,413 (a) An asset that will be retired in the near future and substantially in advance of its previously expected retirement date is subject to abandonment accounting. In the second quarter of 2021, the operator of Columbia received approval from MISO to retire Columbia Units 1 and 2. The co-owners intend to retire Unit 1 by the end of 2023 and Unit 2 by the end of 2024. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. As of December 31, 2021, early retirement of Columbia was probable. "Plant anticipated to be retired early" in table above is the net book value of these generating units. Assets for Columbia Unit 1 and Unit 2 are currently included in rate base, and MGE continues to depreciate them on a straight-line basis using the composite depreciation rates approved by the PSCW that included retirement dates of 2029 for Unit 1 and 2038 for Unit 2. If it becomes probable that regulators will disallow full recovery or a return on the remaining net book value of a generating unit that is either abandoned or probable of being abandoned, an impairment loss would be required. An impairment loss would be recorded for the difference of the remaining net book value of the generating unit that is greater than the present value of the amount expected to be recovered from ratepayers. No impairment was recorded as of December 31, 2021. (b) Three major projects were placed in service in 2021. Electric only utility projects were O'Brien Solar Fields completed in May and Badger Hollow I completed in November. Implementation of a new Customer Information System, an electric and gas utility project, went live in September . |
Leases (Tables)
Leases (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Leases [Abstract] | |
Lease Cost | The following table shows lease expense for the years ended December 31: (In thousands) 2021 2020 Income Statement Location Finance lease expense: Amortization of leased assets $ 1,609 $ 1,694 Depreciation and amortization Interest on lease liabilities 771 784 Interest expense, net Operating lease expense 506 319 Other operations and maintenance Total lease expense $ 2,886 $ 2,797 |
Lease Balance Sheet | The following table shows the lease assets and liabilities on the consolidated balance sheets as of December 31: (In thousands) 2021 2020 Balance Sheet Location Lease assets: Finance lease assets $ 15,545 $ 15,682 Property, plant, and equipment, net Operating lease assets 7,961 5,988 Other deferred assets and other Total lease assets $ 23,506 $ 21,670 Lease liabilities: Finance lease liabilities - current $ 1,050 $ 1,066 Other current liabilities Finance lease liabilities - long-term 17,322 17,532 Finance lease liabilities Operating lease liabilities - current 161 171 Other current liabilities Operating lease liabilities - long-term 7,965 5,840 Other deferred liabilities and other Total lease liabilities $ 26,498 $ 24,609 |
Other Financial Information | The following table shows other lease information for the years ended December 31: (In thousands) 2021 2020 Cash paid for amounts included in the measurement of lease liabilities: Finance leases - Financing cash flows $ 1,495 $ 1,149 Finance leases - Operating cash flows 771 784 Operating leases - Operating cash flows 362 319 Lease assets obtained in exchange for lease liabilities: Finance leases 1,026 1,480 Operating leases 2,178 5,791 |
Weighted Average And Discount Rate | The following table shows the weighted average remaining lease terms and discounts as of December 31: Weighted-average remaining lease terms (in years): 2021 2020 Finance leases 38 37 Operating leases 35 34 Weighted-average discount rates: Finance leases 4.30 % 4.32 % Operating leases 3.07 % 2.84 % |
Lessee Operating Lease Liability Maturity | The following table shows maturities of lease liabilities as of December 31: (In thousands) Finance Operating 2022 $ 1,787 $ 399 2023 1,616 329 2024 1,163 304 2025 965 294 2026 845 299 Thereafter 39,726 12,133 Subtotal 46,102 13,758 Less: Present value discount ( 27,730 ) ( 5,632 ) Lease liability 18,372 8,126 Less: current portion ( 1,050 ) ( 161 ) Noncurrent lease liability $ 17,322 $ 7,965 |
Lessee Finance Lease Liability Maturity | The following table shows maturities of lease liabilities as of December 31: (In thousands) Finance Operating 2022 $ 1,787 $ 399 2023 1,616 329 2024 1,163 304 2025 965 294 2026 845 299 Thereafter 39,726 12,133 Subtotal 46,102 13,758 Less: Present value discount ( 27,730 ) ( 5,632 ) Lease liability 18,372 8,126 Less: current portion ( 1,050 ) ( 161 ) Noncurrent lease liability $ 17,322 $ 7,965 |
Joint Plant Ownership (Tables)
Joint Plant Ownership (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Regulated Operations [Abstract] | |
Schedule of Joint Plant Ownership | The following table shows MGE's interest in utility plant in service, and the related accumulated depreciation reserves and other information related to MGE's jointly owned facilities: (In thousands, except for Columbia (a) Elm Road (b) West Campus (c) Forward Wind (d) Two Creeks (e) Badger Hollow (f) Ownership interest 19 % 8.33 % 55 % 12.8 % 33 % 33 % Share of generation (MW) 211 MW 106 MW 157 MW 18 MW 50 MW 100 MW For the year ended December 31, Operating expense - 2021 $ 33,284 $ 18,478 $ (g) $ 669 $ 953 $ 140 Operating expense - 2020 27,127 17,259 (g) 664 118 — Operating expense - 2019 32,604 19,661 (g) 642 — — As of December 31, 2021 Utility plant $ — $ 202,604 $ 114,090 $ 34,084 $ 67,814 $ 69,178 Accumulated depreciation — ( 39,279 ) ( 34,907 ) ( 14,945 ) ( 2,932 ) ( 227 ) Plant anticipated to be 158,983 — — — — — Construction work in progress 2,388 898 493 21 — 19,748 As of December 31, 2020 Utility plant $ 289,597 $ 203,847 $ 115,657 $ 34,028 $ 67,577 $ — Accumulated depreciation ( 118,742 ) ( 36,964 ) ( 36,580 ) ( 14,092 ) ( 225 ) — Construction work in progress 997 697 677 — — 63,140 (a) In February 2021, MGE and the other co-owners announced plans to retire Columbia, a two unit coal-fired generation facility located in Portage, Wisconsin. The co-owners intend to retire Unit 1 by the end of 2023 and Unit 2 by the end of 2024. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. As of December 31, 2021, early retirement of Columbia was probable. See Footnote 4 for further information. (b) Two coal-fired generating units in Oak Creek, Wisconsin. In November 2021, MGE announced plans to end the use of coal as a primary fuel at the Elm Road Units and transition the plant to natural gas. (c) MGE Power West Campus and the UW jointly own the West Campus Cogeneration Facility (WCCF) located on the UW campus in Madison, Wisconsin. The UW owns a controlling interest in the chilled-water and steam plants, which are used to meet the needs for air-conditioning and steam-heat capacity for the UW campus. MGE Power West Campus owns a controlling interest in the electric generation plant, which is leased and operated by MGE. (d) The Forward Wind Energy Center (Forward Wind) consists of 86 wind turbines located near Brownsville, Wisconsin. (e) The Two Creeks solar generation array is located in the Town of Two Creeks and the City of Two Rivers in Manitowoc and Kewaunee Counties, Wisconsin. Date of commercial operation of the solar array was November 2020. (f) The Badger Hollow I and II solar farm is located in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb. Badger Hollow I and II. Date of commercial operation of Badger Hollow I was November 2021. Construction of Badger Hollow II is expected to be completed in March 2023. (g) Operating charges are allocated to the UW based on formulas contained in the operating agreement. Under the provisions of this arrangement, the UW is required to reimburse MGE for their allocated portion of fuel and operating expenses. For the years ended December 31, 2021, 2020, and 2019, the UW's allocated share of fuel and operating costs was $ 6.2 million, $ 5.2 million, and $ 6.6 million, respectively. |
Investments (Tables)
Investments (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Investments Disclosure [Abstract] | |
Equity Method and Other Investments | a. Equity Securities, Equity Method Investments, and Other Investments. MGE Energy MGE (In thousands) 2021 2020 2021 2020 Equity securities $ 20,529 $ 17,906 $ 230 $ 603 Equity method investments: ATC and ATC Holdco 75,862 74,423 — — Other 39 39 — — Total equity method investments 75,901 74,462 — — Other investments 2,324 2,308 — — Total $ 98,754 $ 94,676 $ 230 $ 603 During the years ended December 31, 2021, 2020, and 2019, certain investments were liquidated. As a result of these liquidations, the following was received: MGE Energy MGE (In thousands) 2021 2020 2019 2021 2020 2019 Cash proceeds $ 1,684 $ 622 $ 216 $ — $ — $ 2 Gain (loss) on sale 1,543 379 580 — — ( 343 ) |
Equity Method Investments Summarized Financial Data | Equity earnings from investments are recorded as "Other income" on the consolidated statements of income of MGE Energy. For the years ended December 31, MGE Transco recorded the following: (In thousands) 2021 2020 2019 Equity earnings from investment in ATC $ 9,774 $ 10,167 $ 9,889 Dividends received from ATC 7,832 8,633 7,347 Capital contributions to ATC — 1,249 3,018 In January 2022, MGE Transco made a $ 1.2 million capital contribution to ATC. (In thousands) Income statement data for the year ended December 31, 2021 2020 2019 Operating revenues $ 754,838 $ 758,117 $ 744,371 Operating expenses ( 376,153 ) ( 372,463 ) ( 373,527 ) Other income 1,144 1,922 48 Interest expense, net ( 115,089 ) ( 112,818 ) ( 110,490 ) Earnings before members' income taxes $ 264,740 $ 274,758 $ 260,402 Balance sheet data as of December 31, 2021 2020 Current assets $ 89,747 $ 92,735 Noncurrent assets 5,628,127 5,400,538 Total assets $ 5,717,874 $ 5,493,273 Current liabilities $ 436,918 $ 310,749 Long-term debt 2,513,009 2,512,246 Other noncurrent liabilities 421,997 378,205 Members' equity 2,345,950 2,292,073 Total members' equity and liabilities $ 5,717,874 $ 5,493,273 |
Regulatory Assets and Liabili_2
Regulatory Assets and Liabilities (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Regulatory Assets and Liabilities Disclosure [Abstract] | |
Regulatory Assets and Liabilities | The following regulatory assets and liabilities are reflected in MGE's consolidated balance sheets as of December 31: (In thousands) 2021 2020 Regulatory Assets Asset retirement obligation $ 13,081 $ 11,935 Deferred fuel costs 3,292 — Deferred bad debt expense 5,600 3,750 Debt related costs 8,173 8,586 Deferred pension and other postretirement costs 1,017 5,280 Derivatives — 13,989 Leases 2,992 2,748 Tax recovery related to AFUDC equity 10,347 8,952 Unfunded pension and other postretirement liability 63,728 101,594 Other 782 418 Total Regulatory Assets $ 109,012 $ 157,252 Regulatory Liabilities Deferred fuel savings $ — $ 5,047 Derivatives 617 — Elm Road — 1,957 Income taxes 110,817 129,856 Non-ARO removal costs 29,694 28,197 Pension and other postretirement service costs 11,451 7,524 Deferred pension and other postretirement costs 8,112 — Purchased gas adjustment 1,448 1,832 Renewable energy credits 1,001 802 Transmission 223 7,669 Other 300 1,019 Total Regulatory Liabilities $ 163,663 $ 183,903 |
Income Taxes (Tables)
Income Taxes (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Income Tax Disclosure [Abstract] | |
Income Tax Provision | On a consolidated and separate company basis, the income tax provision consists of the following provision (benefit) components for the years ended December 31: MGE Energy MGE (In thousands) 2021 2020 2019 2021 2020 2019 Current payable: Federal $ ( 2,589 ) $ 4,179 $ 8,017 $ ( 3,434 ) $ 3,716 $ 7,616 State 3,002 5,095 4,647 3,163 4,790 4,608 Net-deferred: Federal ( 1,473 ) 6,181 3,510 ( 1,951 ) 4,756 2,242 State 6,310 4,182 3,702 5,605 3,787 3,044 Amortized investment tax credits ( 1,135 ) ( 214 ) ( 92 ) ( 1,135 ) ( 214 ) ( 92 ) Total income tax provision $ 4,115 $ 19,423 $ 19,784 $ 2,248 $ 16,835 $ 17,418 |
Effective Tax Rate Reconciliation | The consolidated income tax provision differs from the amount computed by applying the statutory federal income tax rate to income before income taxes, as follows: MGE Energy MGE 2021 2020 2019 2021 2020 2019 Statutory federal income tax rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % State income taxes, net of federal benefit 6.2 6.3 6.2 6.2 6.3 6.1 Amortized investment tax credits ( 1.5 ) ( 0.2 ) ( 0.1 ) ( 1.5 ) ( 0.2 ) ( 0.1 ) Credit for electricity from wind energy ( 6.0 ) ( 6.2 ) ( 5.7 ) ( 6.4 ) ( 6.8 ) ( 6.2 ) AFUDC equity, net ( 0.9 ) ( 1.2 ) ( 0.3 ) ( 1.0 ) ( 1.4 ) ( 0.3 ) Amortization of utility excess deferred tax (a) ( 14.8 ) ( 2.0 ) ( 2.4 ) ( 15.8 ) ( 2.2 ) ( 2.7 ) Other, net, individually insignificant ( 0.3 ) ( 0.3 ) ( 0.1 ) ( 0.3 ) ( 0.3 ) ( 0.1 ) Effective income tax rate 3.7 % 17.4 % 18.6 % 2.2 % 16.4 % 17.7 % (a) Included are impacts of the 2017 Tax Act for the regulated utility for excess deferred taxes recognized using a normalization method of accounting in recognition of IRS rules that restrict the rate at which excess deferred taxes may be returned to utility customers. For the years ended December 31, 2021, 2020 and 2019, MGE recognized $ 2.6 million, $ 2.2 million, and $ 2.6 million, respectively. Included in the 2021 rate settlement was a one-time return to customers of the electric portion of excess deferred taxes related to the 2017 Tax Act not restricted by IRS normalization rules. For the year ended December 31, 2021, MGE recognized $ 13.2 million. |
Deferred Tax Liabilities (Assets) | The significant components of deferred tax assets and liabilities that appear on the consolidated balance sheets as of December 31 are as follows: MGE Energy MGE (In thousands) 2021 2020 2021 2020 Deferred tax assets Investment in ATC $ 20,868 $ 21,688 $ — $ — Federal tax credits 39,161 19,199 39,161 20,080 Accrued expenses 11,053 11,115 11,047 11,105 Pension and other postretirement benefits 24,888 35,446 24,888 35,446 Deferred tax regulatory account 42,401 41,318 42,401 41,318 Derivatives 241 3,852 241 3,852 Leases 7,218 6,704 7,218 6,704 Other 17,390 14,073 17,442 14,125 Gross deferred income tax assets 163,220 153,395 142,398 132,630 Less valuation allowance — ( 38 ) — ( 38 ) Net deferred income tax assets $ 163,220 $ 153,357 $ 142,398 $ 132,592 Deferred tax liabilities Property-related $ 274,613 $ 257,397 $ 274,613 $ 257,397 Investment in ATC 52,731 51,518 — — Bond transactions 534 595 534 595 Pension and other postretirement benefits 34,781 45,658 34,781 45,658 Derivatives 241 3,852 241 3,852 Tax deductible prepayments 10,222 9,059 10,210 9,059 Leases 7,218 6,704 7,218 6,704 Other 14,029 10,045 13,686 9,717 Gross deferred income tax liabilities 394,369 384,828 341,283 332,982 Deferred income taxes, net $ 231,149 $ 231,471 $ 198,885 $ 200,390 |
Summary Of Tax Credit Carryforwards | The components of federal and state tax benefit carryovers as of December 31, are as follows: MGE Energy MGE (In thousands) 2021 2020 2021 2020 Federal tax credits $ 39,161 $ 19,199 $ 39,161 $ 20,080 State net operating losses 3 621 3 621 Valuation allowances for state net operating losses ( 3 ) ( 621 ) ( 3 ) ( 621 ) |
Unrecognized Tax Benefits and Interest | A tabular reconciliation of unrecognized tax benefits and interest is as follows: (In thousands) Unrecognized Tax Benefits: 2021 2020 2019 Unrecognized tax benefits, January 1, $ 2,281 $ 2,093 $ 1,949 Additions based on tax positions related to the current year 714 796 741 Additions based on tax positions related to the prior years - - 84 Reductions based on tax positions related to the prior years ( 642 ) ( 608 ) ( 681 ) Unrecognized tax benefits, December 31, $ 2,353 $ 2,281 $ 2,093 (In thousands) Interest on Unrecognized Tax Benefits: 2021 2020 2019 Accrued interest on unrecognized tax benefits, January 1, $ 154 $ 176 $ 191 Reduction in interest expense on uncertain tax positions ( 98 ) ( 124 ) ( 137 ) Interest expense on uncertain tax positions 94 102 122 Accrued interest on unrecognized tax benefits, December 31, $ 150 $ 154 $ 176 |
Tax Years that Remain Subject to Examination | The following table shows tax years that remain subject to examination by major jurisdiction: Taxpayer Open Years MGE Energy and consolidated subsidiaries in federal return 2018 through 2021 MGE Energy Wisconsin combined reporting corporation return 2017 through 2021 |
Pension Plans and Other Postr_2
Pension Plans and Other Postretirement Benefits (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Compensation and Retirement Disclosure [Abstract] | |
Schedule of Benefit Obligations and Change in Plan Assets | a. Benefit Obligations and Plan Assets. (In thousands) Pension Benefits Other Postretirement Benefits Change in Benefit Obligations: 2021 2020 2021 2020 Net benefit obligation as of January 1, $ 461,215 $ 410,651 $ 86,360 $ 80,901 Service cost 5,730 5,296 1,448 1,264 Interest cost 9,109 12,210 1,549 2,278 Plan participants' contributions — — 992 1,009 Actuarial loss (gain) (a) 3,871 50,325 ( 685 ) 5,907 Gross benefits paid ( 19,259 ) ( 17,267 ) ( 5,405 ) ( 5,245 ) Less: federal subsidy on benefits paid (b) — — 267 246 Benefit obligation as of December 31, $ 460,666 $ 461,215 $ 84,526 $ 86,360 Change in Plan Assets: Fair value of plan assets as of January 1, $ 429,538 $ 386,033 $ 51,735 $ 48,889 Actual return on plan assets 61,487 58,935 6,814 6,514 Employer contributions 2,187 1,837 708 568 Plan participants' contributions — — 992 1,009 Gross benefits paid ( 19,259 ) ( 17,267 ) ( 5,405 ) ( 5,245 ) Fair value of plan assets at end of year 473,953 429,538 54,844 51,735 Funded Status as of December 31, $ 13,287 $ ( 31,677 ) $ ( 29,682 ) $ ( 34,625 ) (a) In 2020, lower discount rates were the primary driver of the actuarial loss. (b) In 2003, the Medicare Prescription Drug, Improvement and Modernization Act of 2003 was signed into law authorizing Medicare to provide prescription drug benefits to retirees. For the years ended December 31, 2021 and 2020, the subsidy due to MGE was $ 0.3 million and $ 0.2 million, respectively. |
Schedule of Amounts Recognized in the Consolidated Balance Sheet | The amounts recognized in the consolidated balance sheets to reflect the funded status of the plans as of December 31 are as follows: Pension Benefits Other Postretirement Benefits (In thousands) 2021 2020 2021 2020 Long-term asset $ 58,757 $ 13,873 $ — $ — Current liability ( 2,342 ) ( 2,139 ) — — Long-term liability ( 43,128 ) ( 43,411 ) ( 29,682 ) ( 34,625 ) Net liability $ 13,287 $ ( 31,677 ) $ ( 29,682 ) $ ( 34,625 ) |
Amounts Recognized in Regulatory Asset | The following table shows the amounts that have not yet been recognized in our net periodic benefit cost as of December 31 and are recorded as regulatory assets in the consolidated balance sheets: Pension Benefits Other Postretirement Benefits (In thousands) 2021 2020 2021 2020 Net actuarial loss $ 57,777 $ 92,553 $ 6,256 $ 10,986 Prior service benefit ( 20 ) ( 144 ) ( 297 ) ( 1,816 ) Transition obligation — — 12 15 Total $ 57,757 $ 92,409 $ 5,971 $ 9,185 |
Schedule of Projected Benefit Obligations in Excess of Plan Assets | The projected benefit obligation and fair value of plan assets for pension plans with a projected benefit obligation in excess of plan assets were as follows : (In thousands) Pension Benefits Projected Benefit Obligation in Excess of Plan Assets 2021 2020 Projected benefit obligation, end of year $ 45,470 $ 45,550 Fair value of plan assets, end of year — — |
Schedule of Accumulated Benefit Obligations in Excess of Plan Assets | The accumulated benefit obligation and fair value of plan assets with an accumulated benefit obligation in excess of plan assets were as follows: (In thousands) Pension Benefits Other Postretirement Benefits Accumulated Benefit Obligation in Excess of Plan Assets 2021 2020 2021 2020 Accumulated benefit obligation, end of year $ 43,831 $ 43,384 $ 84,526 $ 86,360 Fair value of plan assets, end of year — — 54,844 51,735 |
Net Periodic Benefit Costs | (In thousands) Pension Benefits Other Postretirement Benefits Components of Net Periodic Benefit Cost: 2021 (a) 2020 (a) 2019 (a) 2021 (a) 2020 (a) 2019 (a) Service cost $ 5,730 $ 5,296 $ 4,692 $ 1,448 $ 1,264 $ 1,110 Interest cost 9,109 12,210 14,302 1,549 2,278 2,893 Expected return on assets ( 29,487 ) ( 27,229 ) ( 22,786 ) ( 3,277 ) ( 3,154 ) ( 2,723 ) Amortization of: Transition obligation — — — 3 3 3 Prior service (credit) cost ( 124 ) ( 114 ) ( 117 ) ( 1,518 ) ( 2,669 ) ( 2,669 ) Actuarial loss 6,646 5,357 7,379 493 217 401 Net periodic benefit cost (credit) $ ( 8,126 ) $ ( 4,480 ) $ 3,470 $ ( 1,302 ) $ ( 2,061 ) $ ( 985 ) (a) During 2019, MGE deferred approximately $ 6.2 million of pension and other postretirement costs. During 2021 and 2020 , MGE collected approximately $ 4.3 million and $ 0.9 million, respectively, of pension and other postretirement costs, which reduced the amount deferred in prior years. The impact of the deferral has not been reflected in the table above. See Footnote 8 for further information. During the year ended December 30, 2021, MGE deferred $ 8.1 million of savings from 2021 employee benefit plan costs and recorded as a regulatory liability. The deferred savings has not been reflected in the table above. See Footnote 8 for additional information. |
Plan Assumptions | c. Plan Assumptions. The weighted-average assumptions used to determine the benefit obligations were as follows for the years ended December 31: Pension Benefits Other Postretirement Benefits 2021 2020 2021 2020 Discount rate 2.94 % 2.70 % 2.85 % 2.52 % Rate of compensation increase 3.19 % 3.22 % N/A N/A Assumed health care cost trend rates: Health care cost trend rate assumed for next year N/A N/A 5.75 % 5.75 % Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) N/A N/A 4.75 % 4.75 % Year that the rate reaches the ultimate trend rate N/A N/A 2027 2027 MGE uses individual spot rates, instead of a weighted average of the yield curve spot rates, for measuring the service cost and interest cost components of net periodic benefit cost. The weighted-average assumptions used to determine the net periodic cost were as follows for the years ended December 31: Pension Benefits Other Postretirement Benefits 2021 2020 2019 2021 2020 2019 Discount rate 2.70 % 3.42 % 4.32 % 2.52 % 3.30 % 4.24 % Expected rate of return on plan assets 7.00 % 7.20 % 7.20 % 6.61 % 6.75 % 6.72 % Rate of compensation increase 3.23 % 3.26 % 3.25 % N/A N/A N/A |
Fair Value of Plan Assets by Asset Category | The asset allocation for MGE's pension plans as of December 31, 2021 and 2020, and the target allocation for 2022, by asset category, follows: Target Percentage of Plan Allocation 2021 2020 Equity securities (a) 63.0 % 65.0 % 69.0 % Fixed income securities 30.0 % 29.0 % 25.0 % Real estate 7.0 % 6.0 % 6.0 % Total 100.0 % 100.0 % 100.0 % (a) Target allocations for equity securities are broken out as follows: 45.5 % United States equity and 17.5 % non-United States equity. The fair values of MGE's plan assets by asset category as of December 31 are as follows: (In thousands) 2021 2020 Cash and Cash Equivalents $ 1,428 $ 1,180 Equity Securities: U.S. Large Cap 162,060 151,218 U.S. Mid Cap 38,755 37,389 U.S. Small Cap 47,657 50,456 International Blend 87,781 87,461 Fixed Income Securities: Short-Term Fund 5,222 4,215 High Yield Bond 25,190 22,683 Long Duration Bond 119,867 92,657 Real Estate 37,170 30,005 Insurance Continuance Fund 1,599 1,506 Fixed Rate Fund 2,068 2,503 Total $ 528,797 $ 481,273 |
Benefit Payments, Fiscal Year Maturity | The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid as follows: Pension Other Postretirement Benefits (In thousands) Pension Benefits Gross Postretirement Benefits Expected Medicare Part D Subsidy Net Postretirement Benefits 2022 $ 19,736 $ 4,713 $ ( 304 ) $ 4,409 2023 20,474 4,982 ( 333 ) 4,649 2024 21,197 5,281 ( 363 ) 4,918 2025 21,897 5,533 ( 395 ) 5,138 2026 22,497 5,567 ( 430 ) 5,137 2027 - 2031 117,862 27,651 ( 2,541 ) 25,110 |
Share-Based Compensation (Table
Share-Based Compensation (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Performance Units [Member] | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |
Performance Unit Graded Vesting Schedule | The following activity occurred : 2021 Nonvested awards January 1, 7,003 Granted 10,187 Vested — Undistributed vested awards (c) ( 3,320 ) Nonvested awards December 31, 13,870 Weighted average fair Value of each nonvested award $ 104.76 Weighted average estimated payout % based on performance criteria 127.4 % (c) Represents performance units that vested but were not distributed to retirement-eligible employees during 2021. |
Restricted Stock Units Equity Awards [Member] | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |
Performance Unit Graded Vesting Schedule | The following activity occurred: 2021 Units Weighted Average Grant Date Fair Value (per share) Nonvested awards January 1, — N/A Granted 16,267 $ 65.83 Vested — Undistributed vested awards (a) ( 3,141 ) $ 65.83 Nonvested awards December 31, 13,126 $ 65.83 (a) Represents restricted stock units that vested but were not distributed to retirement-eligible employees during 2021. |
Restricted Stock Units Liability Awards [Member] | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |
Performance Unit Graded Vesting Schedule | The following activity occurred: 2021 Nonvested awards January 1, 7,003 Granted — Vested — Undistributed vested awards (b) ( 939 ) Nonvested awards December 31, 6,064 (b) Represents restricted stock units that vested but were not distributed to retirement-eligible employees during 2021. |
2006 Performance Unit Plan and 2013 Director Incentive Plan [Member] | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |
Performance Unit Graded Vesting Schedule | The following activity occurred: 2021 Director Performance Nonvested awards January 1, 4,286 17,420 Granted — — Vested ( 2,814 ) ( 11,660 ) Nonvested awards December 31, 1,472 5,760 |
Notes Payable to Banks, Comme_2
Notes Payable to Banks, Commercial Paper, and Lines of Credit (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Debt Disclosure [Abstract] | |
Schedule of Short-Term Borrowings | Information concerning short-term borrowings is shown below: (In thousands) MGE Energy (a) MGE As of December 31, 2021 2020 2021 2020 Available capacity under line of credit $ 143,815 $ 96,815 $ 93,815 $ 46,815 Short-term debt outstanding $ 5,500 $ 52,500 $ 5,500 $ 52,500 Letters of credit issued inside credit facilities $ 685 $ 685 $ 685 $ 685 Weighted-average interest rate 0.15 % 0.15 % 0.15 % 0.15 % Year Ended December 31, Maximum short-term borrowings $ 64,000 $ 52,500 $ 64,000 $ 52,500 Average short-term borrowings $ 28,583 $ 6,393 $ 28,583 $ 6,393 Weighted-average interest rate 0.15 % 0.43 % 0.15 % 0.43 % (a) MGE Energy short-term borrowings include MGE Energy and MGE lines of credit and MGE commercial paper. |
Long-Term Debt (Tables)
Long-Term Debt (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Debt Disclosure [Abstract] | |
Schedule of Long-Term Debt | December 31, (In thousands) 2021 2020 First Mortgage Bonds: (a) 7.70 %, 2028 Series $ 1,200 $ 1,200 Tax Exempt Debt: 2.05 %, 2023 Series, Industrial Development Revenue Bonds 19,300 19,300 Medium-Term Notes: (c) 6.12 %, due 2028 20,000 20,000 7.12 %, due 2032 25,000 25,000 6.247 %, due 2037 25,000 25,000 Total Medium-Term Notes 70,000 70,000 Other Long-Term Debt: (d) 3.09 %, due 2023 (e) 30,000 30,000 3.29 %, due 2026 (e) 15,000 15,000 3.11 %, due 2027 (e) 30,000 30,000 2.94 %, due 2029 (e) 50,000 50,000 2.48 %, due 2031 (e)(b) 60,000 — 5.68 %, due 2033 (f) 21,510 22,762 5.19 %, due 2033 (f) 14,133 14,985 2.63 %, due 2033 (e)(b) 40,000 — 5.26 %, due 2040 (e) 15,000 15,000 5.04 %, due 2040 (g) 30,139 31,806 4.74 %, due 2041 (g) 19,167 20,167 4.38 %, due 2042 (e) 28,000 28,000 4.42 %, due 2043 (e) 20,000 20,000 4.47 %, due 2048 (e) 20,000 20,000 3.76 %, due 2052 (e) 40,000 40,000 4.19 %, due 2048 (e) 60,000 60,000 4.24 %, due 2053 (e) 20,000 20,000 4.34 %, due 2058 (e) 20,000 20,000 Total Other Long-Term Debt 532,949 437,720 Long-term debt due within one year ( 4,889 ) ( 4,771 ) Unamortized discount and debt issuance costs ( 4,349 ) ( 4,146 ) Total Long-Term Debt $ 614,211 $ 519,303 (a) MGE's utility plant is subject to the lien of its Indenture of Mortgage and Deed of Trust, under which its first mortgage bonds are issued. The Mortgage Indenture provides that dividends or any other distribution or purchase of MGE shares may not be made if the aggregate amount thereof since December 31, 1945, would exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2021, approximately $ 604.3 million was available for the payment of dividends under this covenant. (b) In May 2021, MGE entered into a private placement Note Purchase Agreement in which it committed to issue $60 million of new long-term debt (Series A) and $40 million of new long-term debt (Series B). Funding occurred on June 15, 2021, for Series B and August 27, 2021, for Series A. The proceeds of the debt financing were used to assist with capital expenditures and other corporate obligations. (c) The indenture under which MGE's Medium-Term notes are issued provides that those notes will be entitled to be equally and ratably secured in the event that MGE issues any additional first mortgage bonds. (d) Unsecured notes issued pursuant to various Note Purchase Agreements with one or more purchasers. The notes are not issued under, or governed by, MGE's Indenture dated as of September 1, 1998, which governs MGE's Medium-Term Notes. (e) Issued by MGE. Under that Note Purchase Agreement: (i) note holders have the right to require MGE to repurchase their notes at par in the event of an acquisition of beneficial ownership of 30 % or more of the outstanding voting stock of MGE Energy, (ii) MGE must maintain a ratio of its consolidated indebtedness to consolidated total capitalization not to exceed a maximum of 65 %, and (iii) MGE cannot issue "Priority Debt" in an amount exceeding 20 % of its consolidated assets. Priority Debt is defined as any indebtedness of MGE secured by liens other than specified liens permitted by the Note Purchase Agreement and certain unsecured indebtedness of certain subsidiaries. As of December 31, 2021 , MGE was in compliance with the covenant requirements. (f) Issued by MGE Power West Campus. The Note Purchase Agreements require MGE Power West Campus to maintain a projected debt service coverage ratio of not less than 1.25 to 1.00, and debt to total capitalization ratio of not more than 0.65 to 1.00. The notes are secured by a collateral assignment of lease payments that MGE is making to MGE Power West Campus for use of the WCCF pursuant to a long-term lease. As of December 31, 2021 , MGE Power West Campus was in compliance with the covenant requirements. (g) Issued by MGE Power Elm Road. The Note Purchase Agreement requires MGE Power Elm Road to maintain a projected and actual debt service coverage ratio at the end of any calendar quarter of not less than 1.25 to 1.00 for the trailing 12-month period. The notes are secured by a collateral assignment of lease payments that MGE is making to MGE Power Elm Road for use of the Elm Road Units pursuant to long-term leases. As of December 31, 2021 , MGE Power Elm Road was in compliance with the covenant requirements. |
Schedule of Long-Term Debt Maturities | Below is MGE Energy's and MGE's aggregate maturities for all long-term debt for years following December 31, 2021. (In thousands) 2022 2023 2024 2025 2026 Thereafter Long-term debt maturities $ 4,889 $ 54,314 $ 5,146 $ 5,285 $ 20,433 $ 533,382 |
Commitments and Contingencies (
Commitments and Contingencies (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Commitments and Contingencies Disclosure [Abstract] | |
Contractual Obligation, Fiscal Year Maturity Schedule | As of December 31, 2021, the future minimum commitments related to these purchase contracts were as follows: (In thousands) 2022 2023 2024 2025 2026 Thereafter Coal (a) $ 20,662 $ 11,752 $ 4,394 $ 937 $ — $ — Natural gas Transportation and storage (b) 23,307 23,922 23,922 23,922 13,772 11,525 Supply (c) 26,987 — — — — — Purchase power (d) 14,249 5,061 5,162 5,266 5,371 5,723 Renewable energy (e) 7,999 1,185 698 714 730 25,876 Other 7,265 1,720 891 105 107 798 $ 100,469 $ 43,640 $ 35,067 $ 30,944 $ 19,980 $ 43,922 (a) Total coal commitments for the Columbia and Elm Road Units, including transportation. Fuel procurement for MGE's jointly owned Columbia and Elm Road Units is handled by WPL and WEPCO, respectively, who are the operators of those facilities. (b) MGE's natural gas transportation and storage contracts require fixed monthly payments for firm supply pipeline transportation and storage capacity. The pricing components of the fixed monthly payments for the transportation and storage contracts are approved by FERC but may be subject to change. (c) These commitments include market-based pricing. (d) MGE has several purchase power agreements to help meet future electric supply requirements. (e) Operational commitments for solar and wind facilities. |
Other Commitments | MGE has several other commitments related to various projects. Payments for these commitments are expected to be as follows: (In thousands) 2022 2023 2024 2025 2026 Thereafter Other commitments $ 333 $ 333 $ 333 $ 333 $ 333 $ 2,666 |
Asset Retirement Obligations (T
Asset Retirement Obligations (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Asset Retirement Obligation Disclosure [Abstract] | |
Change in Asset Retirement Obligations | The following table summarizes the change in AROs. Amounts include conditional AROs . (In thousands) 2021 2020 Balance as of January 1, $ 31,196 $ 28,355 Liabilities incurred (a) 8,589 3,503 Accretion expense 1,526 1,366 Liabilities settled ( 354 ) ( 372 ) Revisions in estimated cash flows (b) 5,623 ( 1,656 ) Balance as of December 31, $ 46,580 $ 31,196 (a) In 2021, MGE recorded an obligation of $ 4.9 million and $ 3.4 million, respectively, for the fair value of its legal liability for AROs associated with Badger Hollow I and other completed renewable projects. In 2020, MGE recorded an obligation of $ 3.2 million for the fair value of its legal liability for AROs associated with Two Creeks. See Footnote 6 for additional information on Badger Hollow I and Two Creeks . (b) In 2021, MGE revised the AROs associated with certain Columbia assets. |
Derivative and Hedging Instru_2
Derivative and Hedging Instruments (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Gross Notional Volume of Open Derivatives | The gross notional volume of open derivatives is as follows: December 31, 2021 December 31, 2020 Commodity derivative contracts 278,000 MWh 259,080 MWh Commodity derivative contracts 5,735,000 Dth 6,030,000 Dth FTRs 2,127 MW 2,869 MW PPA 250 MW 850 MW |
Fair Value of Derivative Instruments on the Balance Sheet | The following table summarizes the fair value of the derivative instruments on the consolidated balance sheets. All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, instruments are netted with the same counterparty under a master netting agreement as well as the netting of collateral. (In thousands) Derivative Derivative Balance Sheet Location December 31, 2021 Commodity derivative contracts (a) $ 2,959 $ 811 Other current assets Commodity derivative contracts (a) 420 38 Other deferred charges FTRs 227 — Other current assets PPA N/A 2,140 Derivative liability (current) December 31, 2020 Commodity derivative contracts (b) $ 617 $ 593 Other current assets Commodity derivative contracts (b) 189 39 Other deferred charges FTRs — 23 Other current liabilities PPA N/A 10,160 Derivative liability (current) PPA N/A 3,980 Derivative liability (long-term) (a) As of December 31, 2021, MGE received collateral of $ 1.3 million from counterparties under a master netting agreement for outstanding exchange traded derivative positions. The fair value of the derivative asset disclosed in this table has not been reduced for the collateral received. (b) No collateral was posted against derivative positions as of December 31, 2020 . |
Offsetting Assets | The following tables show the effect of netting arrangements for recognized derivative assets and liabilities that are subject to a master netting arrangement or similar arrangement on the consolidated balance sheets. Offsetting of Derivative Assets (In thousands) Gross Gross Amounts Collateral Posted Net Amount December 31, 2021 Commodity derivative contracts $ 3,379 $ ( 849 ) $ ( 1,254 ) $ 1,276 FTRs 227 — — 227 December 31, 2020 Commodity derivative contracts $ 806 $ ( 632 ) $ — $ 174 |
Offsetting Liabilities | Offsetting of Derivative Liabilities (In thousands) Gross Gross Amounts Collateral Posted Net Amount December 31, 2021 Commodity derivative contracts $ 849 $ ( 849 ) $ — $ — PPA 2,140 — — 2,140 December 31, 2020 Commodity derivative contracts $ 632 $ ( 632 ) $ — $ — FTRs 23 — — 23 PPA 14,140 — — 14,140 |
Derivative Gains and Losses in Balance Sheet | The following tables summarize the unrealized and realized gains/losses related to the derivative instruments on the consolidated balance sheets and the consolidated statements of income. 2021 2020 Current and Other Current and Other (In thousands) Balance as of January 1, $ 13,989 $ 1,162 $ 26,875 $ 1,100 Unrealized gain ( 23,173 ) — ( 4,895 ) — Realized gain (loss) reclassified to a deferred account 2,563 ( 2,563 ) ( 2,232 ) 2,232 Realized gain (loss) reclassified to income statement 6,004 2,171 ( 5,759 ) ( 2,170 ) Balance as of December 31, $ ( 617 ) $ 770 $ 13,989 $ 1,162 |
Derivative Gains and Losses in Income Statement | Realized Losses (Gains) 2021 2020 (In thousands) Fuel for Electric Cost of Fuel for Electric Cost of Year Ended December 31: Commodity derivative contracts $ ( 3,948 ) $ ( 1,700 ) $ 2,566 $ 1,729 FTRs ( 605 ) — 63 — PPA ( 1,922 ) — 3,571 — |
Fair Value of Financial Instr_2
Fair Value of Financial Instruments (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Fair Value Disclosures [Abstract] | |
Estimated Fair Market Value of Financial Instruments | The estimated fair market value of financial instruments are as follows: December 31, 2021 December 31, 2020 (In thousands) Carrying Amount Fair Carrying Amount Fair MGE Energy Assets: Cash and cash equivalents $ 17,438 $ 17,438 $ 44,738 $ 44,738 Liabilities: Short-term debt - commercial paper 5,500 5,500 52,500 52,500 Long-term debt (a) 623,449 729,914 528,220 639,271 MGE Assets: Cash and cash equivalents $ 6,401 $ 6,401 $ 4,103 $ 4,103 Liabilities: Short-term debt - commercial paper 5,500 5,500 52,500 52,500 Long-term debt (a) 623,449 729,914 528,220 639,271 (a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $ 4.3 million and $ 4.1 million as of December 31, 2021 and 2020 , respectively. |
Assets and Liabilities Measured at Fair Value on a Recurring Basis | The following table presents the balances of assets and liabilities measured at fair value on a recurring basis. Fair Value as of December 31, 2021 (In thousands) Total Level 1 Level 2 Level 3 MGE Energy Assets: Derivatives, net (b) $ 3,606 $ 1,170 $ — $ 2,436 Exchange-traded investments 1,296 1,296 — — Total Assets $ 4,902 $ 2,466 $ — $ 2,436 Liabilities: Derivatives, net (b) $ 2,989 $ 731 $ — $ 2,258 Deferred compensation 3,653 — 3,653 — Total Liabilities $ 6,642 $ 731 $ 3,653 $ 2,258 MGE Assets: Derivatives, net (b) $ 3,606 $ 1,170 $ — $ 2,436 Exchange-traded investments 230 230 — — Total Assets $ 3,836 $ 1,400 $ — $ 2,436 Liabilities: Derivatives, net (b) $ 2,989 $ 731 $ — $ 2,258 Deferred compensation 3,653 — 3,653 — Total Liabilities $ 6,642 $ 731 $ 3,653 $ 2,258 Fair Value as of December 31, 2020 (In thousands) Total Level 1 Level 2 Level 3 MGE Energy Assets: Derivatives, net (b) $ 806 $ 436 $ — $ 370 Exchange-traded investments 1,750 1,750 — — Total Assets $ 2,556 $ 2,186 $ — $ 370 Liabilities: Derivatives, net (b) $ 14,795 $ 370 $ — $ 14,425 Deferred compensation 3,509 — 3,509 — Total Liabilities $ 18,304 $ 370 $ 3,509 $ 14,425 MGE Assets: Derivatives, net (b) $ 806 $ 436 $ — $ 370 Exchange-traded investments 603 603 — — Total Assets $ 1,409 $ 1,039 $ — $ 370 Liabilities: Derivatives, net (b) $ 14,795 $ 370 $ — $ 14,425 Deferred compensation 3,509 — 3,509 — Total Liabilities $ 18,304 $ 370 $ 3,509 $ 14,425 (b) As of December 31, 2021 , MGE received collateral of $ 1.3 million from counterparties under a master netting agreement for outstanding exchange traded derivative positions. The fair value of the derivative asset disclosed in this table has not been reduced for the collateral received. No collateral was posted against derivative positions owed to counterparties under a master netting agreement on the consolidated balance sheet as of December 31, 2020 . |
Significant Unobservable Inputs | The following table presents the significant unobservable inputs used in the pricing model. Model Input Significant Unobservable Inputs 2021 2020 Basis adjustment: On peak 94.1 % 94.2 % Off peak 92.4 % 94.5 % Counterparty fuel mix: Internal generation - range 41 %- 66 % 46 %- 65 % Internal generation - weighted average 56.6 % 56.5 % Purchased power - range 59 %- 34 % 54 %- 35 % Purchased power - weighted average 43.4 % 43.5 % |
Changes in Level 3 Assets and Liabilities Measured at Fair Value on a Recurring Basis | The following table summarizes the changes in Level 3 commodity derivative assets and liabilities measured at fair value on a recurring basis. (In thousands) 2021 2020 2019 Balance as of January 1, $ ( 14,055 ) $ ( 26,456 ) $ ( 32,002 ) Realized and unrealized gains (losses): Included in regulatory assets — 12,402 5,545 Included in regulatory liability 14,234 — — Included in other comprehensive income — — — Included in earnings 5,521 ( 6,439 ) ( 3,765 ) Included in current assets 237 ( 87 ) ( 70 ) Purchases 26,287 22,232 22,974 Sales — — — Issuances — — — Settlements ( 32,046 ) ( 15,707 ) ( 19,138 ) Balance as of December 31, $ 178 $ ( 14,055 ) $ ( 26,456 ) Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities held as of December 31, (c) $ — $ — $ — |
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). (In thousands) Year Ended December 31, 2021 2020 2019 Purchased power expense $ 6,192 $ ( 5,888 ) $ ( 3,334 ) Cost of gas sold expense ( 671 ) ( 551 ) ( 431 ) Total $ 5,521 $ ( 6,439 ) $ ( 3,765 ) (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. |
Revenue (Tables)
Revenue (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Revenue from Contract with Customer [Abstract] | |
Disaggregation of Revenue | Revenues disaggregated by revenue source were as follows: (In thousands) Year Ended December 31, Electric revenues 2021 2020 2019 Residential $ 151,646 $ 146,431 $ 140,006 Commercial 210,475 198,043 213,265 Industrial 12,529 11,514 12,772 Other-retail/municipal 35,169 32,915 35,174 Total retail 409,819 388,903 401,217 Sales to the market 9,499 4,015 5,664 Other revenues 968 774 1,404 Total electric revenues 420,286 393,692 408,285 Gas revenues Residential 110,442 88,765 95,146 Commercial/Industrial 68,895 49,682 59,051 Total retail 179,337 138,447 154,197 Gas transportation 6,185 5,713 5,293 Other revenues 98 101 385 Total gas revenues 185,620 144,261 159,875 Non-regulated energy revenues 678 680 695 Total Operating Revenue $ 606,584 $ 538,633 $ 568,855 |
Noncontrolling Interest (Tables
Noncontrolling Interest (Tables) - MGE [Member] | 12 Months Ended |
Dec. 31, 2021 | |
Noncontrolling Interest [Line Items] | |
Noncontrolling Interest in Balance Sheet | The noncontrolling interest on MGE's consolidated balance sheets was as follows: As of December 31, (In thousands) 2021 2020 MGE Power Elm Road (a) $ 101,507 $ 96,856 MGE Power West Campus (a) 47,080 44,340 Total Noncontrolling Interest $ 148,587 $ 141,196 |
Net Income Attributable to Noncontrolling Interest, Net of Tax | The net income attributable to noncontrolling interest, net of tax, was as follows: Years ending December 31, (In thousands) 2021 2020 2019 MGE Power Elm Road (a) $ 15,151 $ 15,184 $ 15,153 MGE Power West Campus (a) 7,240 7,209 7,196 Net Income Attributable to Noncontrolling Interest, Net of Tax $ 22,391 $ 22,393 $ 22,349 (a) MGE Power Elm Road and MGE Power West Campus are not subsidiaries of MGE; however, they have been consolidated in the consolidated financial statements of MGE (see Footnote 3). MGE Power Elm Road and MGE Power West Campus are 100 % owned by MGE Power, and MGE Power is 100 % owned by MGE Energy. MGE Energy's proportionate share of the equity and net income (through its wholly owned subsidiary MGE Power) of MGE Power Elm Road and MGE Power West Campus is classified within the MGE consolidated financial statements as noncontrolling interest . |
Segment Information (Tables)
Segment Information (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Segment Reporting [Abstract] | |
Segment Information | The following table shows segment information for MGE Energy's and MGE's operations: (In thousands) Electric Gas Non-Regulated Energy Transmission Investment All Others Consolidation/ Consolidated Total Year Ended December 31, 2021 Operating revenues $ 420,286 $ 185,620 $ 678 $ — $ — $ — $ 606,584 Interdepartmental revenues 556 22,728 40,866 — — ( 64,150 ) — Total operating revenues 420,842 208,348 41,544 — — ( 64,150 ) 606,584 Depreciation and amortization ( 56,672 ) ( 12,852 ) ( 7,459 ) — — — ( 76,983 ) Operating income (loss) 58,993 25,133 33,936 — ( 768 ) — 117,294 Interest (expense) income, net ( 15,261 ) ( 4,315 ) ( 4,577 ) — 41 — ( 24,112 ) Income tax (provision) benefit 10,672 ( 4,922 ) ( 7,998 ) ( 2,486 ) 619 — ( 4,115 ) Equity in earnings of investments — — — 9,339 ( 69 ) — 9,270 Net income (loss) 63,910 15,511 21,361 6,852 ( 1,873 ) — 105,761 Year Ended December 31, 2020 Operating revenues $ 393,692 $ 144,261 $ 680 $ — $ — $ — $ 538,633 Interdepartmental revenues 765 12,157 40,402 — — ( 53,324 ) — Total operating revenues 394,457 156,418 41,082 — — ( 53,324 ) 538,633 Depreciation and amortization ( 54,658 ) ( 12,049 ) ( 7,481 ) — — — ( 74,188 ) Operating income (loss) 57,847 19,674 33,460 ( 1 ) ( 983 ) — 109,997 Interest (expense) income, net ( 14,446 ) ( 4,370 ) ( 4,826 ) — 121 — ( 23,521 ) Income tax (provision) benefit ( 4,230 ) ( 4,805 ) ( 7,800 ) ( 2,786 ) 198 — ( 19,423 ) Equity in earnings of investments — — — 10,221 — — 10,221 Net income (loss) 50,522 14,167 20,834 7,434 ( 539 ) — 92,418 Year Ended December 31, 2019 Operating revenues $ 408,285 $ 159,875 $ 695 $ — $ — $ — $ 568,855 Interdepartmental revenues 806 16,070 40,020 — — ( 56,896 ) — Total operating revenues 409,091 175,945 40,715 — — ( 56,896 ) 568,855 Depreciation and amortization ( 52,755 ) ( 11,320 ) ( 7,487 ) — — — ( 71,562 ) Operating income (loss) 59,180 19,528 33,084 — ( 882 ) — 110,910 Interest (expense) income, net ( 14,978 ) ( 4,237 ) ( 5,083 ) — 1,235 — ( 23,063 ) Income tax (provision) benefit ( 5,037 ) ( 4,753 ) ( 7,628 ) ( 2,602 ) 236 — ( 19,784 ) Equity in earnings of investments — — — 9,547 — — 9,547 Net income (loss) 46,318 14,088 20,373 6,945 ( 850 ) — 86,874 (In thousands) Electric Gas Non-Regulated Energy Consolidation/ Elimination Entries Consolidated Total Year Ended December 31, 2021 Operating revenues $ 420,286 $ 185,620 $ 678 $ — $ 606,584 Interdepartmental revenues 556 22,728 40,866 ( 64,150 ) — Total operating revenues 420,842 208,348 41,544 ( 64,150 ) 606,584 Depreciation and amortization ( 56,672 ) ( 12,852 ) ( 7,459 ) — ( 76,983 ) Operating income 58,993 25,133 33,936 — 118,062 Interest expense, net ( 15,261 ) ( 4,315 ) ( 4,577 ) — ( 24,153 ) Income tax provision 10,672 ( 4,922 ) ( 7,998 ) — ( 2,248 ) Net income attributable to MGE 63,910 15,511 21,361 ( 22,391 ) 78,391 Year Ended December 31, 2020 Operating revenues $ 393,692 $ 144,261 $ 680 $ — $ 538,633 Interdepartmental revenues 765 12,157 40,402 ( 53,324 ) — Total operating revenues 394,457 156,418 41,082 ( 53,324 ) 538,633 Depreciation and amortization ( 54,658 ) ( 12,049 ) ( 7,481 ) — ( 74,188 ) Operating income 57,847 19,674 33,460 — 110,981 Interest expense, net ( 14,446 ) ( 4,370 ) ( 4,826 ) — ( 23,642 ) Income tax provision ( 4,230 ) ( 4,805 ) ( 7,800 ) — ( 16,835 ) Net income attributable to MGE 50,522 14,167 20,834 ( 22,393 ) 63,130 Year Ended December 31, 2019 Operating revenues $ 408,285 $ 159,875 $ 695 $ — $ 568,855 Interdepartmental revenues 806 16,070 40,020 ( 56,896 ) — Total operating revenues 409,091 175,945 40,715 ( 56,896 ) 568,855 Depreciation and amortization ( 52,755 ) ( 11,320 ) ( 7,487 ) — ( 71,562 ) Operating income 59,180 19,528 33,084 — 111,792 Interest expense, net ( 14,978 ) ( 4,237 ) ( 5,083 ) — ( 24,298 ) Income tax provision ( 5,037 ) ( 4,753 ) ( 7,628 ) — ( 17,418 ) Net income attributable to MGE 46,318 14,088 20,373 ( 22,349 ) 58,430 The following table shows segment information for MGE Energy's and MGE's assets and capital expenditures: Utility Consolidated (In thousands) MGE Energy Electric Gas Non-regulated Energy Transmission Investment (a) All Others Consolidation/ Elimination Entries Total Assets: December 31, 2021 $ 1,525,163 $ 485,345 $ 252,584 $ 75,990 $ 467,954 $ ( 435,130 ) $ 2,371,906 December 31, 2020 1,421,302 444,702 254,298 74,480 495,483 ( 436,614 ) 2,253,651 December 31, 2019 1,308,277 408,001 258,004 71,668 443,278 ( 407,564 ) 2,081,664 Capital Expenditures: Year ended Dec. 31, 2021 $ 115,234 $ 34,071 $ 3,864 $ — $ — $ — $ 153,169 Year ended Dec. 31, 2020 162,210 36,906 4,023 — — — 203,139 Year ended Dec. 31, 2019 125,086 36,193 2,757 — — — 164,036 Utility Consolidated (In thousands) Electric Gas Non-regulated Energy Consolidation/ Elimination Entries Total Assets: December 31, 2021 $ 1,525,163 $ 485,345 $ 252,534 $ ( 267 ) $ 2,262,775 December 31, 2020 1,421,302 444,702 254,248 ( 281 ) 2,119,971 December 31, 2019 1,308,277 408,001 257,954 ( 755 ) 1,973,477 Capital Expenditures: Year ended Dec. 31, 2021 $ 115,234 $ 34,071 $ 3,864 $ — $ 153,169 Year ended Dec. 31, 2020 162,210 36,906 4,023 — 203,139 Year ended Dec. 31, 2019 125,086 36,193 2,757 — 164,036 (a) The Transmission Investment segment represents MGE Energy's investment in equity method investees. |
Summary of Significant Accoun_3
Summary of Significant Accounting Policies (Details-1) - USD ($) | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Trade Receivables, Allowance for Doubtful Accounts, and Concentration Risk | |||
Late payment charge on upaid receivables | 1.00% | ||
Accounts receivable, allowance for credit loss, writeoff | $ 2,200,000 | $ 1,400,000 | |
Accounts receivable, allowance for credit loss, period increase | 3,400,000 | 5,200,000 | |
Accounts receivable, allowance for credit loss | 8,300,000 | 7,100,000 | |
Inventories | |||
Renewable energy credit allowance included in inventory | 1,000,000 | 800,000 | |
Purchased Gas Adjustment Clause | |||
Purchased gas adjustment, over (under) collected | 1,400,000 | 1,800,000 | |
Regional Transmission Organizations | |||
Reduction to sales and purchased power expense from reporting RTO transactions from net basis reporting | 113,600,000 | 61,800,000 | $ 75,600,000 |
Allowance for Funds Used During Construction | |||
AFUDC - equity funds | 5,000,000 | 5,900,000 | 2,300,000 |
AFUDC - borrowed funds | 1,700,000 | 2,100,000 | 800,000 |
Capitalized Software Costs | |||
Capitalized software | 85,800,000 | 20,400,000 | |
Capitalized software - accumulated amortization | 42,600,000 | 36,900,000 | |
Capitalized software amortization | 5,700,000 | 5,100,000 | 5,100,000 |
Capitalized Software Hosting Agreement Costs | |||
Capitalized Computer Software Hosting Agreement Net | 15,600,000 | 14,800,000 | |
Capitalized Computer Software Hosting Agreement Amortization | 2,200,000 | 1,800,000 | 1,400,000 |
Capitalized Computer Software Hosting Agreement Accumulated Amortization | 5,400,000 | 3,200,000 | |
Impairment of Long-Lived Assets | |||
Impairment of long-lived assets | $ 0 | 0 | 0 |
Excise taxes | |||
License fee tax rate, electric, retail sales | 3.19% | ||
License fee tax rate, electric, resale by purchaser | 1.59% | ||
License fee tax rate, natural gas | 0.97% | ||
License fee tax expense | $ 13,500,000 | $ 14,100,000 | $ 13,900,000 |
Minimum [Member] | |||
Capitalized Software Hosting Agreement Costs | |||
Capitalized software hosting agreement, useful life | 3 years | ||
Minimum [Member] | Capitalized Software [Member] | |||
Property, Plant, and Equiptment | |||
Property, plant, and equipment, useful life | 5 years | ||
Maximum [Member] | |||
Capitalized Software Hosting Agreement Costs | |||
Capitalized software hosting agreement, useful life | 10 years | ||
Maximum [Member] | Capitalized Software [Member] | |||
Property, Plant, and Equiptment | |||
Property, plant, and equipment, useful life | 15 years | ||
PSCW [Member] | |||
Allowance for Funds Used During Construction | |||
Authorized AFUDC rate | 50.00% | 50.00% | 50.00% |
Authorized AFUDC rate - Signficiant projects (100%) | 100.00% | 100.00% | 100.00% |
Rate at which AFUDC was capitalized | 6.89% | 7.03% | 7.00% |
Electric [Member] | |||
Property, Plant, and Equiptment | |||
Composite straight-line depreciation rates | 3.20% | 3.50% | 3.60% |
Gas [Member] | |||
Property, Plant, and Equiptment | |||
Composite straight-line depreciation rates | 2.20% | 2.20% | 2.10% |
Non Regulated Energy [Member] | |||
Property, Plant, and Equiptment | |||
Composite straight-line depreciation rates | 2.40% | 2.30% | 2.30% |
MGE Power Elm Road [Member] | |||
Principles of Consolidation | |||
Ownership percentage by parent | 100.00% | ||
MGE Power West Campus [Member] | |||
Principles of Consolidation | |||
Ownership percentage by parent | 100.00% |
Summary of Significant Accoun_4
Summary of Significant Accounting Policies (Details-2) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | Dec. 31, 2018 |
Cash Cash Equivalents And Restricted Cash [Line Items] | ||||
Cash and cash equivalents | $ 17,438 | $ 44,738 | ||
Restricted cash | 847 | 644 | ||
Receivable - margin account | 550 | 1,657 | ||
Cash, cash equivalents, and restricted cash | 18,835 | 47,039 | $ 25,814 | $ 84,929 |
MGE [Member] | ||||
Cash Cash Equivalents And Restricted Cash [Line Items] | ||||
Cash and cash equivalents | 6,401 | 4,103 | ||
Restricted cash | 847 | 644 | ||
Receivable - margin account | 550 | 1,657 | ||
Cash, cash equivalents, and restricted cash | $ 7,798 | $ 6,404 | $ 5,529 | $ 6,670 |
Variable Interest Entities (Det
Variable Interest Entities (Details) $ in Thousands | Dec. 31, 2021USD ($)MW | Dec. 31, 2020USD ($)MW | |
Variable Interest Entity [Line Items] | |||
In-service utility plant, net | $ 1,828,171 | $ 1,630,286 | |
Construction work in progress | 50,603 | 139,099 | |
Accrued interest and accrued (prepaid) taxes | 10,385 | 8,539 | |
Deferred income taxes | 231,149 | 231,471 | |
Unamortized discount and debt issuance costs | $ 4,349 | $ 4,146 | |
Other Variable Interest Entities | |||
Other variable interest entities, purchase power agreement, plant capacity (in MW) | MW | 13 | 13 | |
MGE Power Elm Road [Member] | |||
Variable Interest Entity [Line Items] | |||
In-service utility plant, net | $ 163,325 | $ 166,883 | |
Construction work in progress | 898 | 697 | |
Affiliate receivables, current and noncurrent | 0 | 0 | |
Accrued interest and accrued (prepaid) taxes | 37 | 2,701 | |
Deferred income taxes | 30,696 | 30,646 | |
Long-term debt | [1] | 48,968 | 51,590 |
Noncontrolling interest | 101,507 | 96,856 | |
Unamortized discount and debt issuance costs | 300 | 400 | |
MGE Power West Campus [Member] | |||
Variable Interest Entity [Line Items] | |||
In-service utility plant, net | 79,183 | 79,077 | |
Construction work in progress | 493 | 677 | |
Affiliate receivables, current and noncurrent | 2,211 | 2,803 | |
Accrued interest and accrued (prepaid) taxes | 75 | 671 | |
Deferred income taxes | 14,726 | 14,521 | |
Long-term debt | [1] | 35,563 | 37,652 |
Noncontrolling interest | 47,080 | 44,340 | |
Unamortized discount and debt issuance costs | $ 100 | $ 100 | |
[1] | MGE Power Elm Road's long-term debt includes debt issuance costs of $ 0.3 million and $ 0.4 million as of December 31, 2021 and 2020, respectively. The debt is secured by a collateral assignment of lease payments that MGE makes to MGE Power Elm Road for use of the Elm Road Units pursuant to the related long-term leases. MGE Power West Campus's long-term debt includes debt issuance costs of $ 0.1 million as of December 31, 2021 and 2020 . The debt is secured by a collateral assignment of lease payments that MGE makes to MGE Power West Campus for use of the cogeneration facility pursuant to the long-term lease. See Footnote 14 for further information on the long-term debt securities |
Property, Plant, and Equipmen_2
Property, Plant, and Equipment (Details) - USD ($) $ in Thousands | 12 Months Ended | |||
Dec. 31, 2021 | Dec. 31, 2020 | |||
Property, Plant and Equipment [Line Items] | ||||
Plant anticipated to be retired early | $ 158,983 | [1] | $ 0 | |
In-service utility plant, net | 1,828,171 | 1,630,286 | ||
Construction work in progress | 50,603 | 139,099 | ||
Total property, plant, and equipment | 1,878,774 | 1,769,385 | ||
Columbia Units [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
Plant anticipated to be retired early | [2] | 158,983 | ||
Impairment of Long-Lived Assets | ||||
Impairment of long-lived assets | 0 | |||
First Mortgage Bonds [Member] | 7.70%, 2028 Series [Member] | ||||
Plant related debt items | ||||
Long-term debt, gross | [3] | 1,200 | 1,200 | |
Regulated [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
In-service utility plant, gross | 2,221,906 | 2,105,108 | ||
Less: Accumulated depreciation and amortization | [1] | 636,804 | 721,382 | |
In-service utility plant, net | 1,585,102 | 1,383,726 | ||
Construction work in progress | [4] | 49,211 | 137,725 | |
Electric [Member] | Regulated [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
In-service utility plant, gross | [1],[4] | 1,516,533 | 1,608,658 | |
Gas [Member] | Regulated [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
In-service utility plant, gross | 546,390 | 496,450 | ||
Non Regulated Energy [Member] | Non-regulated [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
In-service utility plant, gross | 317,881 | 320,691 | ||
Less: Accumulated depreciation and amortization | 74,812 | 74,131 | ||
In-service utility plant, net | 243,069 | 246,560 | ||
Construction work in progress | 1,392 | 1,374 | ||
MGE [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
Plant anticipated to be retired early | 158,983 | [1] | 0 | |
In-service utility plant, net | 1,828,199 | 1,630,314 | ||
Construction work in progress | 50,603 | 139,099 | ||
Total property, plant, and equipment | 1,878,802 | 1,769,413 | ||
MGE [Member] | Regulated [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
In-service utility plant, gross | 2,221,934 | 2,105,136 | ||
Less: Accumulated depreciation and amortization | [1] | 636,804 | 721,382 | |
In-service utility plant, net | 1,585,130 | 1,383,754 | ||
Construction work in progress | [4] | 49,211 | 137,725 | |
MGE [Member] | Electric [Member] | Regulated [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
In-service utility plant, gross | [1],[4] | 1,516,550 | 1,608,675 | |
MGE [Member] | Gas [Member] | Regulated [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
In-service utility plant, gross | 546,401 | 496,461 | ||
MGE [Member] | Non Regulated Energy [Member] | Non-regulated [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
In-service utility plant, gross | 317,881 | 320,691 | ||
Less: Accumulated depreciation and amortization | 74,812 | 74,131 | ||
In-service utility plant, net | 243,069 | 246,560 | ||
Construction work in progress | $ 1,392 | $ 1,374 | ||
[1] | An asset that will be retired in the near future and substantially in advance of its previously expected retirement date is subject to abandonment accounting. In the second quarter of 2021, the operator of Columbia received approval from MISO to retire Columbia Units 1 and 2. The co-owners intend to retire Unit 1 by the end of 2023 and Unit 2 by the end of 2024. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. As of December 31, 2021, early retirement of Columbia was probable. "Plant anticipated to be retired early" in table above is the net book value of these generating units. Assets for Columbia Unit 1 and Unit 2 are currently included in rate base, and MGE continues to depreciate them on a straight-line basis using the composite depreciation rates approved by the PSCW that included retirement dates of 2029 for Unit 1 and 2038 for Unit 2. If it becomes probable that regulators will disallow full recovery or a return on the remaining net book value of a generating unit that is either abandoned or probable of being abandoned, an impairment loss would be required. An impairment loss would be recorded for the difference of the remaining net book value of the generating unit that is greater than the present value of the amount expected to be recovered from ratepayers. No impairment was recorded as of December 31, 2021. | |||
[2] | In February 2021, MGE and the other co-owners announced plans to retire Columbia, a two unit coal-fired generation facility located in Portage, Wisconsin. The co-owners intend to retire Unit 1 by the end of 2023 and Unit 2 by the end of 2024. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. As of December 31, 2021, early retirement of Columbia was probable. See Footnote 4 for further information. | |||
[3] | MGE's utility plant is subject to the lien of its Indenture of Mortgage and Deed of Trust, under which its first mortgage bonds are issued. The Mortgage Indenture provides that dividends or any other distribution or purchase of MGE shares may not be made if the aggregate amount thereof since December 31, 1945, would exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2021, approximately $ 604.3 million was available for the payment of dividends under this covenant. | |||
[4] | Three major projects were placed in service in 2021. Electric only utility projects were O'Brien Solar Fields completed in May and Badger Hollow I completed in November. Implementation of a new Customer Information System, an electric and gas utility project, went live in September . |
Leases (Details-1)
Leases (Details-1) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2021 | Dec. 31, 2020 | |
Lease Cost [Abstract] | ||
Amortization of leased assets, Depreciation and amortization | $ 1,609 | $ 1,694 |
Interest on lease liabilities, Interest expense, net | 771 | 784 |
Operating lease expense, Other operations and maintenance | 506 | 319 |
Total lease expense | $ 2,886 | $ 2,797 |
Leases (Details-2)
Leases (Details-2) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 |
Lessee Disclosure [Line Items] | ||
Finance lease assets, net | $ 15,545 | $ 15,682 |
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration] | Property, plant, and equipment, net | Property, plant, and equipment, net |
Operating lease assets | $ 7,961 | $ 5,988 |
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration] | Other deferred assets and other | Other deferred assets and other |
Total lease assets | $ 23,506 | $ 21,670 |
Finance lease liabilities - current | $ 1,050 | $ 1,066 |
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration] | Other current liabilities | Other current liabilities |
Finance lease liabilities - long-term | $ 17,322 | $ 17,532 |
Operating lease liabilities - current | $ 161 | $ 171 |
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration] | Other current liabilities | Other current liabilities |
Operating lease liabilities - long-term | $ 7,965 | $ 5,840 |
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration] | Other deferred liabilities and other | Other deferred liabilities and other |
Total lease liabilities | $ 26,498 | $ 24,609 |
Leases (Details-3)
Leases (Details-3) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2021 | Dec. 31, 2020 | |
Lessee Disclosure [Abstract] | ||
Finance leases - Financing cash flows | $ 1,495 | $ 1,149 |
Finance leases - Operating cash flows | 771 | 784 |
Operating leases - operating cash flows | 362 | 319 |
Lease assets obtained in exchange for lease liabilities - finance leases | 1,026 | 1,480 |
Lease assets obtained in exchange for lease liabilities - operating leases | $ 2,178 | $ 5,791 |
Leases (Details-4)
Leases (Details-4) | Dec. 31, 2021 | Dec. 31, 2020 |
Lessee Disclosure [Abstract] | ||
Weighted average remaining lease term (years) finance leases | 38 years | 37 years |
Weighted average remaining lease term (years) operating leases | 35 years | 34 years |
Weighted average discount rate finance leases | 4.30% | 4.32% |
Weighted average discount rate operating leases | 3.07% | 2.84% |
Leases (Details-5)
Leases (Details-5) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 |
Finance Lease Liabilities Payments Due [Abstract] | ||
2022 | $ 1,787 | |
2023 | 1,616 | |
2024 | 1,163 | |
2025 | 965 | |
2026 | 845 | |
Thereafter | 39,726 | |
Undiscounted finance lease liability | 46,102 | |
Less: Present value discount | (27,730) | |
Finance lease liability | 18,372 | |
Less: current portion | (1,050) | $ (1,066) |
Finance lease liabilities | 17,322 | 17,532 |
Operating Lease Liabilities Payments Due [Abstract] | ||
2022 | 399 | |
2023 | 329 | |
2024 | 304 | |
2025 | 294 | |
2026 | 299 | |
Thereafter | 12,133 | |
Undiscounted operating lease liability | 13,758 | |
Less: Present value discount | (5,632) | |
Operating Lease Liability | 8,126 | |
Less: current portion | (161) | (171) |
Operating lease liabilities - long-term | $ 7,965 | $ 5,840 |
Joint Plant Ownership (Details)
Joint Plant Ownership (Details) $ in Thousands | 12 Months Ended | ||||
Dec. 31, 2021USD ($)MW | Dec. 31, 2020USD ($) | Dec. 31, 2019USD ($) | |||
Jointly Owned Plants, Net Plant Ownership [Abstract] | |||||
Plant anticipated to be retired early | $ 158,983 | [1] | $ 0 | ||
MGE [Member] | |||||
Jointly Owned Plants, Net Plant Ownership [Abstract] | |||||
Plant anticipated to be retired early | 158,983 | [1] | 0 | ||
Columbia Units [Member] | |||||
Jointly Owned Plants, Net Plant Ownership [Abstract] | |||||
Plant | [2] | 0 | 289,597 | ||
Accumulated depreciation | [2] | 0 | (118,742) | ||
Plant anticipated to be retired early | [2] | 158,983 | |||
Construction work in progress | [2] | $ 2,388 | 997 | ||
Columbia Units [Member] | MGE [Member] | |||||
Jointly Owned Utility Plant Interests [Line Items] | |||||
Jointly owned utility plant, plant capacity (in MW) | MW | [2] | 211 | |||
Jointly owned utility plant, ownership interest | [2] | 19.00% | |||
Jointly owned utility plant, fuel, operating, and maintenance expense | [2] | $ 33,284 | 27,127 | $ 32,604 | |
Elm Road Units [Member] | MGE [Member] | |||||
Jointly Owned Utility Plant Interests [Line Items] | |||||
Jointly owned utility plant, fuel, operating, and maintenance expense | [3] | $ 18,478 | 17,259 | 19,661 | |
Elm Road Units [Member] | MGE Power Elm Road [Member] | |||||
Jointly Owned Utility Plant Interests [Line Items] | |||||
Jointly owned utility plant, plant capacity (in MW) | MW | [3] | 106 | |||
Jointly owned utility plant, ownership interest | [3] | 8.33% | |||
Jointly Owned Plants, Net Plant Ownership [Abstract] | |||||
Plant | [3] | $ 202,604 | 203,847 | ||
Accumulated depreciation | [3] | (39,279) | (36,964) | ||
Plant anticipated to be retired early | [3] | 0 | |||
Construction work in progress | [3] | 898 | 697 | ||
Forward Wind [Member] | |||||
Jointly Owned Plants, Net Plant Ownership [Abstract] | |||||
Plant | [4] | 34,084 | 34,028 | ||
Accumulated depreciation | [4] | (14,945) | (14,092) | ||
Plant anticipated to be retired early | [4] | 0 | |||
Construction work in progress | [4] | $ 21 | 0 | ||
Forward Wind [Member] | MGE [Member] | |||||
Jointly Owned Utility Plant Interests [Line Items] | |||||
Jointly owned utility plant, plant capacity (in MW) | MW | [4] | 18 | |||
Jointly owned utility plant, ownership interest | [4] | 12.80% | |||
Jointly owned utility plant, fuel, operating, and maintenance expense | [4] | $ 669 | 664 | 642 | |
West Campus [Member] | UW [Member] | |||||
Jointly Owned Utility Plant Interests [Line Items] | |||||
Jointly owned utility plant, fuel, operating, and maintenance expense | [5] | $ 6,200 | 5,200 | 6,600 | |
West Campus [Member] | MGE Power West Campus [Member] | |||||
Jointly Owned Utility Plant Interests [Line Items] | |||||
Jointly owned utility plant, plant capacity (in MW) | MW | [6] | 157 | |||
Jointly owned utility plant, ownership interest | [6] | 55.00% | |||
Jointly Owned Plants, Net Plant Ownership [Abstract] | |||||
Plant | [6] | $ 114,090 | 115,657 | ||
Accumulated depreciation | [6] | (34,907) | (36,580) | ||
Plant anticipated to be retired early | [6] | 0 | |||
Construction work in progress | [6] | 493 | 677 | ||
Two Creeks [Member] | |||||
Jointly Owned Plants, Net Plant Ownership [Abstract] | |||||
Plant | [7] | 67,814 | 67,577 | ||
Accumulated depreciation | [7] | (2,932) | (225) | ||
Plant anticipated to be retired early | [7] | 0 | |||
Construction work in progress | [7] | $ 0 | 0 | ||
Two Creeks [Member] | MGE [Member] | |||||
Jointly Owned Utility Plant Interests [Line Items] | |||||
Jointly owned utility plant, plant capacity (in MW) | MW | [7] | 50 | |||
Jointly owned utility plant, ownership interest | [7] | 33.00% | |||
Jointly owned utility plant, fuel, operating, and maintenance expense | [7] | $ 953 | 118 | 0 | |
Badger Hollow I and II [Member] | |||||
Jointly Owned Plants, Net Plant Ownership [Abstract] | |||||
Plant | [8] | 69,178 | 0 | ||
Accumulated depreciation | [8] | (227) | 0 | ||
Plant anticipated to be retired early | [8] | 0 | |||
Construction work in progress | [8] | $ 19,748 | 63,140 | ||
Badger Hollow I and II [Member] | MGE [Member] | |||||
Jointly Owned Utility Plant Interests [Line Items] | |||||
Jointly owned utility plant, plant capacity (in MW) | MW | [8] | 100 | |||
Jointly owned utility plant, ownership interest | [8] | 33.00% | |||
Jointly owned utility plant, fuel, operating, and maintenance expense | [8] | $ 140 | $ 0 | $ 0 | |
[1] | An asset that will be retired in the near future and substantially in advance of its previously expected retirement date is subject to abandonment accounting. In the second quarter of 2021, the operator of Columbia received approval from MISO to retire Columbia Units 1 and 2. The co-owners intend to retire Unit 1 by the end of 2023 and Unit 2 by the end of 2024. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. As of December 31, 2021, early retirement of Columbia was probable. "Plant anticipated to be retired early" in table above is the net book value of these generating units. Assets for Columbia Unit 1 and Unit 2 are currently included in rate base, and MGE continues to depreciate them on a straight-line basis using the composite depreciation rates approved by the PSCW that included retirement dates of 2029 for Unit 1 and 2038 for Unit 2. If it becomes probable that regulators will disallow full recovery or a return on the remaining net book value of a generating unit that is either abandoned or probable of being abandoned, an impairment loss would be required. An impairment loss would be recorded for the difference of the remaining net book value of the generating unit that is greater than the present value of the amount expected to be recovered from ratepayers. No impairment was recorded as of December 31, 2021. | ||||
[2] | In February 2021, MGE and the other co-owners announced plans to retire Columbia, a two unit coal-fired generation facility located in Portage, Wisconsin. The co-owners intend to retire Unit 1 by the end of 2023 and Unit 2 by the end of 2024. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. As of December 31, 2021, early retirement of Columbia was probable. See Footnote 4 for further information. | ||||
[3] | Two coal-fired generating units in Oak Creek, Wisconsin. In November 2021, MGE announced plans to end the use of coal as a primary fuel at the Elm Road Units and transition the plant to natural gas. | ||||
[4] | The Forward Wind Energy Center (Forward Wind) consists of 86 wind turbines located near Brownsville, Wisconsin. | ||||
[5] | Operating charges are allocated to the UW based on formulas contained in the operating agreement. Under the provisions of this arrangement, the UW is required to reimburse MGE for their allocated portion of fuel and operating expenses. For the years ended December 31, 2021, 2020, and 2019, the UW's allocated share of fuel and operating costs was $ 6.2 million, $ 5.2 million, and $ 6.6 million, respectively. | ||||
[6] | MGE Power West Campus and the UW jointly own the West Campus Cogeneration Facility (WCCF) located on the UW campus in Madison, Wisconsin. The UW owns a controlling interest in the chilled-water and steam plants, which are used to meet the needs for air-conditioning and steam-heat capacity for the UW campus. MGE Power West Campus owns a controlling interest in the electric generation plant, which is leased and operated by MGE. | ||||
[7] | The Two Creeks solar generation array is located in the Town of Two Creeks and the City of Two Rivers in Manitowoc and Kewaunee Counties, Wisconsin. Date of commercial operation of the solar array was November 2020. | ||||
[8] | The Badger Hollow I and II solar farm is located in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb. Badger Hollow I and II. Date of commercial operation of Badger Hollow I was November 2021. Construction of Badger Hollow II is expected to be completed in March 2023. |
Investments (Details-1)
Investments (Details-1) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Equity Securities [Abstract] | |||
Equity securities | $ 20,529 | $ 17,906 | |
Equity method investments: [Abstract] | |||
Equity method investments | 75,901 | 74,462 | |
Other Investments | 2,324 | 2,308 | |
Total investments | 98,754 | 94,676 | |
Results of Investment Liquidation [Abstract] | |||
Proceeds from sale of investments | 1,684 | 622 | $ 216 |
Gain (loss) on sale of investments | 1,543 | 379 | 580 |
ATC and ATC Holdco [Member] | |||
Equity method investments: [Abstract] | |||
Equity method investments | 75,862 | 74,423 | |
Other Equity Method Investments [Member] | |||
Equity method investments: [Abstract] | |||
Equity method investments | 39 | 39 | |
MGE [Member] | |||
Equity Securities [Abstract] | |||
Equity securities | 230 | 603 | |
Equity method investments: [Abstract] | |||
Equity method investments | 0 | 0 | |
Other Investments | 0 | 0 | |
Total investments | 230 | 603 | |
Results of Investment Liquidation [Abstract] | |||
Proceeds from sale of investments | 0 | 0 | 2 |
Gain (loss) on sale of investments | 0 | 0 | $ (343) |
MGE [Member] | ATC and ATC Holdco [Member] | |||
Equity method investments: [Abstract] | |||
Equity method investments | 0 | 0 | |
MGE [Member] | Other Equity Method Investments [Member] | |||
Equity method investments: [Abstract] | |||
Equity method investments | $ 0 | $ 0 |
Investments (Details-2)
Investments (Details-2) - USD ($) $ in Thousands | 1 Months Ended | 12 Months Ended | ||
Jan. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Schedule Of Equity Method Investments [Line Items] | ||||
Equity earnings of investments | $ 9,270 | $ 10,221 | $ 9,889 | |
Dividends from investment | 7,832 | 8,998 | 7,347 | |
Capital contributions to investments | 4,027 | 5,601 | 7,813 | |
MGE Energy [Member] | ||||
Schedule Of Equity Method Investments [Line Items] | ||||
Equity earnings of investments | 107,883 | 92,922 | 87,728 | |
MGE Transco [Member] | ATC [Member] | ||||
Schedule Of Equity Method Investments [Line Items] | ||||
Equity earnings of investments | 9,774 | 10,167 | 9,889 | |
Dividends from investment | 7,832 | 8,633 | 7,347 | |
Capital contributions to investments | $ 0 | $ 1,249 | 3,018 | |
Ownership interest in equity-method investee | 3.60% | 3.60% | ||
MGE Transco [Member] | ATC [Member] | Subsequent Event [Member] | ||||
Schedule Of Equity Method Investments [Line Items] | ||||
Capital contributions to investments | $ 1,200 | |||
MGEE Transco [Member] | ATC Holdco [Member] | ||||
Schedule Of Equity Method Investments [Line Items] | ||||
Capital contributions to investments | $ 0 | $ 300 | $ 100 | |
Ownership interest in equity-method investee | 4.40% | 4.40% |
Investments (Details-3)
Investments (Details-3) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Equity method investment summarized assets [Abstract] | |||
Total Current Assets | $ 199,371 | $ 209,519 | |
Total Assets | 2,371,906 | 2,253,651 | $ 2,081,664 |
Equity method investment summarized liabilities and equity [Abstract] | |||
Total Current Liabilities | 117,847 | 190,926 | |
Total Other Credits | 612,380 | 567,422 | |
Total Liabilities and Capitalization | 2,371,906 | 2,253,651 | |
ATC [Member] | |||
Equity method investment summarized income statement [Abstract] | |||
Operating revenues | 754,838 | 758,117 | 744,371 |
Operating expenses | (376,153) | (372,463) | (373,527) |
Other income, net | 1,144 | 1,922 | 48 |
Interest expense, net | (115,089) | (112,818) | (110,490) |
Earnings before members' income taxes | 264,740 | 274,758 | $ 260,402 |
Equity method investment summarized assets [Abstract] | |||
Total Current Assets | 89,747 | 92,735 | |
Total Noncurrent Assets | 5,628,127 | 5,400,538 | |
Total Assets | 5,717,874 | 5,493,273 | |
Equity method investment summarized liabilities and equity [Abstract] | |||
Total Current Liabilities | 436,918 | 310,749 | |
Long-term debt | 2,513,009 | 2,512,246 | |
Total Other Credits | 421,997 | 378,205 | |
Total Equity | 2,345,950 | 2,292,073 | |
Total Liabilities and Capitalization | $ 5,717,874 | $ 5,493,273 |
Investments (Details-4)
Investments (Details-4) - ATC [Member] - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Related party transaction [Line Items] | |||
Related party expenses | $ 32 | $ 30.7 | $ 30.4 |
Due from Related Parties | $ 7 | $ 2.6 |
Regulatory Assets and Liabili_3
Regulatory Assets and Liabilities - Regulatory Assets (Details-1) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 |
Regulatory Assets [Line Items] | ||
Regulatory Assets | $ 109,012 | $ 157,252 |
Asset Retirement Obligation [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory Assets | 13,081 | 11,935 |
Deferred Fuel Costs [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory Assets | 3,292 | 0 |
Deferred Bad Debt Expense [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory Assets | 5,600 | 3,750 |
Debt Related Costs [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory Assets | 8,173 | 8,586 |
Deferred Pension And Other Postretirement Costs [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory Assets | 1,017 | 5,280 |
Derivatives [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory Assets | 0 | 13,989 |
Leases [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory Assets | 2,992 | 2,748 |
Tax Recovery AFUDC Equity [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory Assets | 10,347 | 8,952 |
Unfunded Pension and Other Postretirement Plans Costs [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory Assets | 63,728 | 101,594 |
Other Regulatory Asset [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory Assets | $ 782 | $ 418 |
Regulatory Assets and Liabili_4
Regulatory Assets and Liabilities - Regulatory Liabilities (Details-2) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2021 | Dec. 31, 2020 | |
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | $ 163,663 | $ 183,903 |
MGE [Member] | Public Service Commission of Wisconsin [Member] | Electric Rate Proceeding [Member] | ||
Regulatory Liabilities [Line Items] | ||
Return of unprotected excess deferred taxes | 18,200 | |
Deferred Fuel Savings [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 0 | 5,047 |
Deferred Derivative Gain (Loss) [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 617 | 0 |
Elm Road Regulatory Liability [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 0 | 1,957 |
Income Taxes [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 110,817 | 129,856 |
Non Asset Retirement Obligation Removal Cost [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 29,694 | 28,197 |
Pension and Other Postretirement Plans Costs [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 11,451 | 7,524 |
Deferred Pension And Other Postretirement Costs [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 8,112 | 0 |
Purchased Gas Adjustment [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 1,448 | 1,832 |
Renewable Energy Credits [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 1,001 | 802 |
Transmission Costs [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 223 | 7,669 |
Other Regulatory Liability [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | $ 300 | $ 1,019 |
Rate Matters (Details)
Rate Matters (Details) - USD ($) $ in Millions | 1 Months Ended | 12 Months Ended | ||||
Oct. 31, 2021 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Fuel Rules [Abstract] | ||||||
Deferred fuel rules monitored costs | $ (3.3) | $ 1.5 | ||||
PSCW [Member] | MGE [Member] | ||||||
Rate Proceedings [Abstract] | ||||||
Authorized return on equity, percentage | 9.80% | 9.80% | 9.80% | |||
Approved equity capital structure, percentage | 55.80% | 56.10% | 56.60% | |||
Fuel Rules [Abstract] | ||||||
Fuel rules, bandwidth | 1.00% | 2.00% | ||||
Fuel rules, electric fuel deferred costs upper threshold | 101.00% | |||||
Fuel rules, electric fuel deferred costs lower threshold | 99.00% | |||||
PSCW [Member] | Fuel Rules refund 2020 [Member] | MGE [Member] | ||||||
Fuel Rules [Abstract] | ||||||
Return of electric fuel credit, total | $ 3.2 | |||||
PSCW [Member] | Rate Matters For Future Periods [Member] | MGE [Member] | ||||||
Rate Proceedings [Abstract] | ||||||
Authorized return on equity, percentage | 9.80% | 9.80% | ||||
Approved equity capital structure, percentage | 55.60% | 55.60% | ||||
Electric Rate Proceeding [Member] | PSCW [Member] | MGE [Member] | ||||||
Rate Proceedings [Abstract] | ||||||
Authorized rate increase (decrease), percentage | 0.00% | (0.84%) | (2.24%) | |||
Authorized rate increase (decrease), amount | $ (3.4) | $ (9.2) | ||||
Effects Of The Tax Cuts And Jobs Act [Abstract] | ||||||
Return of unprotected excess deferred taxes | $ 18.2 | |||||
Electric Rate Proceeding [Member] | PSCW [Member] | Rate Matters For Future Periods [Member] | MGE [Member] | ||||||
Rate Proceedings [Abstract] | ||||||
Proposed rate increase (decrease), percentage | 8.81% | |||||
Gas Rate Proceeding [Member] | PSCW [Member] | MGE [Member] | ||||||
Rate Proceedings [Abstract] | ||||||
Authorized rate increase (decrease), percentage | 4.00% | 1.46% | 1.06% | |||
Authorized rate increase (decrease), amount | $ 2.4 | $ 1.7 | ||||
Gas Rate Proceeding [Member] | PSCW [Member] | Rate Matters For Future Periods [Member] | MGE [Member] | ||||||
Rate Proceedings [Abstract] | ||||||
Proposed rate increase (decrease), percentage | 0.96% | 2.15% |
Income Taxes (Details)
Income Taxes (Details) - USD ($) | 12 Months Ended | |||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | ||
Income tax provision components [Abstract] | ||||
Current payable: Federal | $ (2,589,000) | $ 4,179,000 | $ 8,017,000 | |
Current payable: State | 3,002,000 | 5,095,000 | 4,647,000 | |
Net-deferred: Federal | (1,473,000) | 6,181,000 | 3,510,000 | |
Net-deferred: State | 6,310,000 | 4,182,000 | 3,702,000 | |
Amortized investment tax credits | (1,135,000) | (214,000) | (92,000) | |
Total income tax provision | $ 4,115,000 | $ 19,423,000 | $ 19,784,000 | |
Reconciliation of tax provision to statutory federal income tax rate [Abstract] | ||||
Statutory federal income tax rate | 21.00% | 21.00% | 21.00% | |
State income taxes, net of federal benefit | 6.20% | 6.30% | 6.20% | |
Amortized investment tax credits | (1.50%) | (0.20%) | (0.10%) | |
Credit for electricity from wind energy | (6.00%) | (6.20%) | (5.70%) | |
AFUDC equity, net | (0.90%) | (1.20%) | (0.30%) | |
Amortization of utility excess deferred tax | [1] | (14.80%) | (2.00%) | (2.40%) |
Other, net, individually significant | (0.30%) | (0.30%) | (0.10%) | |
Effective income tax rate | 3.70% | 17.40% | 18.60% | |
Components Of Deferred Tax Assets [Abstract] | ||||
Investment in ATC | $ 20,868,000 | $ 21,688,000 | ||
Federal tax credits | 39,161,000 | 19,199,000 | ||
Accrued expenses | 11,053,000 | 11,115,000 | ||
Pension and other postretirement benefits | 24,888,000 | 35,446,000 | ||
Deferred tax regulatory account | 42,401,000 | 41,318,000 | ||
Derivatives | 241,000 | 3,852,000 | ||
Leases | 7,218,000 | 6,704,000 | ||
Other deferred tax assets | 17,390,000 | 14,073,000 | ||
Gross deferred income tax assets | 163,220,000 | 153,395,000 | ||
Less valuation allowance | 0 | (38,000) | ||
Net deferred income tax assets | 163,220,000 | 153,357,000 | ||
Components Of Deferred Tax Liabilities [Abstract] | ||||
Property-related | 274,613,000 | 257,397,000 | ||
Investment in ATC | 52,731,000 | 51,518,000 | ||
Bond transactions | 534,000 | 595,000 | ||
Pension and other postretirement benefits | 34,781,000 | 45,658,000 | ||
Derivatives | 241,000 | 3,852,000 | ||
Tax deductible prepayments | 10,222,000 | 9,059,000 | ||
Leases | 7,218,000 | 6,704,000 | ||
Other deferred tax liabilities | 14,029,000 | 10,045,000 | ||
Gross deferred income tax liabilities | 394,369,000 | 384,828,000 | ||
Deferred income taxes, net | 231,149,000 | 231,471,000 | ||
Operating loss deductions and tax credit carryforwards [Abstract] | ||||
Federal tax credits | 39,161,000 | 19,199,000 | ||
Unrecognized tax benefits [Roll Forward] | ||||
Unrecognized tax benefits, beginning balance | 2,281,000 | 2,093,000 | $ 1,949,000 | |
Additions based on tax positions related to current year | 714,000 | 796,000 | 741,000 | |
Additions based on tax positions related to prior year | 0 | 0 | 84,000 | |
Reductions based on tax positions related to prior years | (642,000) | (608,000) | (681,000) | |
Unrecognized tax benefits, ending balance | 2,353,000 | 2,281,000 | 2,093,000 | |
Interest on unrecognized tax benefits [Roll Forward] | ||||
Accrued interest on unrecognized tax benefits, beginning balance | 154,000 | 176,000 | 191,000 | |
Reduction in interest expense on uncertain tax positions | (98,000) | (124,000) | (137,000) | |
Interest expense on uncertain tax positions | 94,000 | 102,000 | 122,000 | |
Accrued interest on unrecognized tax benefits, ending balance | 150,000 | 154,000 | 176,000 | |
Unrecognized Tax Benefits | ||||
Unrecognized tax benefits permanent differences | 0 | 0 | 100 | |
State [Member] | ||||
Operating loss deductions and tax credit carryforwards [Abstract] | ||||
State net operating losses | 3,000 | 621,000 | ||
Valuation allowances for state net operating losses | (3,000) | (621,000) | ||
Federal [Member] | ||||
Components Of Deferred Tax Assets [Abstract] | ||||
Federal tax credits | 39,161,000 | 19,199,000 | ||
Operating loss deductions and tax credit carryforwards [Abstract] | ||||
Federal tax credits | 39,161,000 | 19,199,000 | ||
Excess Deferred Taxes, Tax Cuts And Jobs Act [Member] | ||||
Effects Of The Tax Cuts And Jobs Act [Abstract] | ||||
Excess deferred tax - Income statement effect | 2,600,000 | 2,200,000 | 2,600,000 | |
Return of unprotected excess deferred taxes | 13,200,000 | |||
MGE [Member] | ||||
Income tax provision components [Abstract] | ||||
Current payable: Federal | (3,434,000) | 3,716,000 | 7,616,000 | |
Current payable: State | 3,163,000 | 4,790,000 | 4,608,000 | |
Net-deferred: Federal | (1,951,000) | 4,756,000 | 2,242,000 | |
Net-deferred: State | 5,605,000 | 3,787,000 | 3,044,000 | |
Amortized investment tax credits | (1,135,000) | (214,000) | (92,000) | |
Total income tax provision | $ 2,248,000 | $ 16,835,000 | $ 17,418,000 | |
Reconciliation of tax provision to statutory federal income tax rate [Abstract] | ||||
Statutory federal income tax rate | 21.00% | 21.00% | 21.00% | |
State income taxes, net of federal benefit | 6.20% | 6.30% | 6.10% | |
Amortized investment tax credits | (1.50%) | (0.20%) | (0.10%) | |
Credit for electricity from wind energy | (6.40%) | (6.80%) | (6.20%) | |
AFUDC equity, net | (1.00%) | (1.40%) | (0.30%) | |
Amortization of utility excess deferred tax | [1] | (15.80%) | (2.20%) | (2.70%) |
Other, net, individually significant | (0.30%) | (0.30%) | (0.10%) | |
Effective income tax rate | 2.20% | 16.40% | 17.70% | |
Components Of Deferred Tax Assets [Abstract] | ||||
Investment in ATC | $ 0 | $ 0 | ||
Federal tax credits | 39,161,000 | 20,080,000 | ||
Accrued expenses | 11,047,000 | 11,105,000 | ||
Pension and other postretirement benefits | 24,888,000 | 35,446,000 | ||
Deferred tax regulatory account | 42,401,000 | 41,318,000 | ||
Derivatives | 241,000 | 3,852,000 | ||
Leases | 7,218,000 | 6,704,000 | ||
Other deferred tax assets | 17,442,000 | 14,125,000 | ||
Gross deferred income tax assets | 142,398,000 | 132,630,000 | ||
Less valuation allowance | 0 | (38,000) | ||
Net deferred income tax assets | 142,398,000 | 132,592,000 | ||
Components Of Deferred Tax Liabilities [Abstract] | ||||
Property-related | 274,613,000 | 257,397,000 | ||
Investment in ATC | 0 | 0 | ||
Bond transactions | 534,000 | 595,000 | ||
Pension and other postretirement benefits | 34,781,000 | 45,658,000 | ||
Derivatives | 241,000 | 3,852,000 | ||
Tax deductible prepayments | 10,210,000 | 9,059,000 | ||
Leases | 7,218,000 | 6,704,000 | ||
Other deferred tax liabilities | 13,686,000 | 9,717,000 | ||
Gross deferred income tax liabilities | 341,283,000 | 332,982,000 | ||
Deferred income taxes, net | 198,885,000 | 200,390,000 | ||
Operating loss deductions and tax credit carryforwards [Abstract] | ||||
Federal tax credits | 39,161,000 | 20,080,000 | ||
MGE [Member] | State [Member] | ||||
Operating loss deductions and tax credit carryforwards [Abstract] | ||||
State net operating losses | 3,000 | 621,000 | ||
Valuation allowances for state net operating losses | (3,000) | (621,000) | ||
MGE [Member] | Federal [Member] | ||||
Components Of Deferred Tax Assets [Abstract] | ||||
Federal tax credits | 39,161,000 | 20,080,000 | ||
Operating loss deductions and tax credit carryforwards [Abstract] | ||||
Federal tax credits | $ 39,161,000 | $ 20,080,000 | ||
[1] | Included are impacts of the 2017 Tax Act for the regulated utility for excess deferred taxes recognized using a normalization method of accounting in recognition of IRS rules that restrict the rate at which excess deferred taxes may be returned to utility customers. For the years ended December 31, 2021, 2020 and 2019, MGE recognized $ 2.6 million, $ 2.2 million, and $ 2.6 million, respectively. Included in the 2021 rate settlement was a one-time return to customers of the electric portion of excess deferred taxes related to the 2017 Tax Act not restricted by IRS normalization rules. For the year ended December 31, 2021, MGE recognized $ 13.2 million. |
Pension Plans and Other Postr_3
Pension Plans and Other Postretirement Benefits (Details-1) - USD ($) | 12 Months Ended | |||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | ||
Defined Benefit Plan, Deferred Pension and Other Postretirement Benefit Plan Costs Recovered [Abstract] | ||||
Defined contribution costs | $ 5,100,000 | $ 4,700,000 | $ 4,400,000 | |
Change in plan assets [Roll Forward] | ||||
Fair value of plan assets as of January 1 | 481,273,000 | |||
Fair value of plan assets as of December 31 | 528,797,000 | 481,273,000 | ||
Amounts recognized in the consolidated balance sheets to reflect funded status of plans [Abstract] | ||||
Long-term asset | 58,757,000 | 13,873,000 | ||
Long-term liability | (73,085,000) | (78,168,000) | ||
Pension Benefits [Member] | ||||
Change in benefit obligations [Roll Forward] | ||||
Net benefit obligation as of January 1 | 461,215,000 | 410,651,000 | ||
Service cost | [1] | 5,730,000 | 5,296,000 | 4,692,000 |
Interest cost | [1] | 9,109,000 | 12,210,000 | 14,302,000 |
Plan participants' contributions | 0 | 0 | ||
Actuarial loss (gain) | [2] | (3,871,000) | (50,325,000) | |
Gross benefits paid | (19,259,000) | (17,267,000) | ||
Less: federal subsidy on benefits paid | [3] | 0 | 0 | |
Benefit obligation as of December 31 | 460,666,000 | 461,215,000 | 410,651,000 | |
Change in plan assets [Roll Forward] | ||||
Fair value of plan assets as of January 1 | 429,538,000 | 386,033,000 | ||
Actual return on plan assets | 61,487,000 | 58,935,000 | ||
Employer contributions | 2,187,000 | 1,837,000 | ||
Plan participant contributions | 0 | 0 | ||
Gross benefits paid | (19,259,000) | (17,267,000) | ||
Fair value of plan assets as of December 31 | 473,953,000 | 429,538,000 | 386,033,000 | |
Funded Status as of December 31 | 13,287,000 | (31,677,000) | ||
Accumulated benefit obligation | 431,300,000 | 430,300,000 | ||
Amounts recognized in the consolidated balance sheets to reflect funded status of plans [Abstract] | ||||
Long-term asset | 58,757,000 | 13,873,000 | ||
Current liability | (2,342,000) | (2,139,000) | ||
Long-term liability | (43,128,000) | (43,411,000) | ||
Net liability | 13,287,000 | (31,677,000) | ||
Amounts recognized in the consolidated balance sheets as regulatory asset [Abstract] | ||||
Net actuarial loss | 57,777,000 | 92,553,000 | ||
Prior service (credit) cost | (20,000) | (144,000) | ||
Transition obligation | 0 | 0 | ||
Total | 57,757,000 | 92,409,000 | ||
Projected benefit obligation in excess of plan assets [Abstract] | ||||
Projected benefit obligation with projected benefit obligation in excess of plan assets, end of year | 45,470,000 | 45,550,000 | ||
Fair value of plan assets with projected benefit obligation in excess of plan assets, end of year | 0 | 0 | ||
Accumulated benefit obligation in excess of plan assets [Abstract] | ||||
Accumulated benefit obligation with accumulated benefit obligation in excess of plan assets, end of year | 43,831,000 | 43,384,000 | ||
Fair value of plan assets with accumulated benefit obligation in excess of plan assets, end of year | 0 | 0 | ||
Postretirement Benefits [Member] | ||||
Change in benefit obligations [Roll Forward] | ||||
Net benefit obligation as of January 1 | 86,360,000 | 80,901,000 | ||
Service cost | [1] | 1,448,000 | 1,264,000 | 1,110,000 |
Interest cost | [1] | 1,549,000 | 2,278,000 | 2,893,000 |
Plan participants' contributions | 992,000 | 1,009,000 | ||
Actuarial loss (gain) | [2] | 685,000 | (5,907,000) | |
Gross benefits paid | (5,405,000) | (5,245,000) | ||
Less: federal subsidy on benefits paid | [3] | 267,000 | 246,000 | |
Benefit obligation as of December 31 | 84,526,000 | 86,360,000 | 80,901,000 | |
Change in plan assets [Roll Forward] | ||||
Fair value of plan assets as of January 1 | 51,735,000 | 48,889,000 | ||
Actual return on plan assets | 6,814,000 | 6,514,000 | ||
Employer contributions | 708,000 | 568,000 | ||
Plan participant contributions | 992,000 | 1,009,000 | ||
Gross benefits paid | (5,405,000) | (5,245,000) | ||
Fair value of plan assets as of December 31 | 54,844,000 | 51,735,000 | $ 48,889,000 | |
Funded Status as of December 31 | (29,682,000) | (34,625,000) | ||
Medicare subsidy due to MGE | 300,000 | 200,000 | ||
Amounts recognized in the consolidated balance sheets to reflect funded status of plans [Abstract] | ||||
Long-term asset | 0 | 0 | ||
Current liability | 0 | 0 | ||
Long-term liability | (29,682,000) | (34,625,000) | ||
Net liability | (29,682,000) | (34,625,000) | ||
Amounts recognized in the consolidated balance sheets as regulatory asset [Abstract] | ||||
Net actuarial loss | 6,256,000 | 10,986,000 | ||
Prior service (credit) cost | (297,000) | (1,816,000) | ||
Transition obligation | 12,000 | 15,000 | ||
Total | 5,971,000 | 9,185,000 | ||
Accumulated benefit obligation in excess of plan assets [Abstract] | ||||
Accumulated benefit obligation with accumulated benefit obligation in excess of plan assets, end of year | 84,526,000 | 86,360,000 | ||
Fair value of plan assets with accumulated benefit obligation in excess of plan assets, end of year | $ 54,844,000 | $ 51,735,000 | ||
[1] | During 2019, MGE deferred approximately $ 6.2 million of pension and other postretirement costs. During 2021 and 2020 , MGE collected approximately $ 4.3 million and $ 0.9 million, respectively, of pension and other postretirement costs, which reduced the amount deferred in prior years. The impact of the deferral has not been reflected in the table above. See Footnote 8 for further information. During the year ended December 30, 2021, MGE deferred $ 8.1 million of savings from 2021 employee benefit plan costs and recorded as a regulatory liability. The deferred savings has not been reflected in the table above. See Footnote 8 for additional information. | |||
[2] | In 2020, lower discount rates were the primary driver of the actuarial loss. | |||
[3] | In 2003, the Medicare Prescription Drug, Improvement and Modernization Act of 2003 was signed into law authorizing Medicare to provide prescription drug benefits to retirees. For the years ended December 31, 2021 and 2020, the subsidy due to MGE was $ 0.3 million and $ 0.2 million, respectively. |
Pension Plans and Other Postr_4
Pension Plans and Other Postretirement Benefits (Details-2) - USD ($) $ in Thousands | 12 Months Ended | |||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | ||
Defined Benefit Plan, Deferred Pension and Other Postretirement Benefit Plan Costs Recovered [Abstract] | ||||
Deferred (recognized) pension and OPEB costs | $ (4,300) | $ (900) | $ 6,200 | |
Deferred savings from 2021 employee benefit plan costs | 8,100 | |||
Pension Benefits [Member] | ||||
Components of Net Periodic Benefit Cost | ||||
Service cost | [1] | 5,730 | 5,296 | 4,692 |
Interest cost | [1] | 9,109 | 12,210 | 14,302 |
Expected return on assets | [1] | (29,487) | (27,229) | (22,786) |
Amortization of: | ||||
Transition obligation | [1] | 0 | 0 | 0 |
Prior service (credit) cost | [1] | (124) | (114) | (117) |
Actuarial loss | [1] | 6,646 | 5,357 | 7,379 |
Net periodic benefit cost (credit) | [1] | (8,126) | (4,480) | 3,470 |
Postretirement Benefits [Member] | ||||
Components of Net Periodic Benefit Cost | ||||
Service cost | [1] | 1,448 | 1,264 | 1,110 |
Interest cost | [1] | 1,549 | 2,278 | 2,893 |
Expected return on assets | [1] | (3,277) | (3,154) | (2,723) |
Amortization of: | ||||
Transition obligation | [1] | (3) | (3) | (3) |
Prior service (credit) cost | [1] | (1,518) | (2,669) | (2,669) |
Actuarial loss | [1] | 493 | 217 | 401 |
Net periodic benefit cost (credit) | [1] | $ (1,302) | $ (2,061) | $ (985) |
[1] | During 2019, MGE deferred approximately $ 6.2 million of pension and other postretirement costs. During 2021 and 2020 , MGE collected approximately $ 4.3 million and $ 0.9 million, respectively, of pension and other postretirement costs, which reduced the amount deferred in prior years. The impact of the deferral has not been reflected in the table above. See Footnote 8 for further information. During the year ended December 30, 2021, MGE deferred $ 8.1 million of savings from 2021 employee benefit plan costs and recorded as a regulatory liability. The deferred savings has not been reflected in the table above. See Footnote 8 for additional information. |
Pension Plans and Other Postr_5
Pension Plans and Other Postretirement Benefits (Details-3) | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Pension Benefits [Member] | |||
Weighted-average assumptions used to determine benefit obligations: | |||
Discount rate | 2.94% | 2.70% | |
Rate of compensation increase | 3.19% | 3.22% | |
Weighted-average assumptions used to determine net periodic cost: | |||
Discount rate | 2.70% | 3.42% | 4.32% |
Long-term rate of return | 7.00% | 7.20% | 7.20% |
Rate of compensation increase | 3.23% | 3.26% | 3.25% |
Postretirement Benefits [Member] | |||
Weighted-average assumptions used to determine benefit obligations: | |||
Discount rate | 2.85% | 2.52% | |
Assumed health care cost trend rates: | |||
Health care cost trend rate assumed for next year | 5.75% | 5.75% | |
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) | 4.75% | 4.75% | |
Year that the rate reaches the ultimate trend rate | 2027 | 2027 | |
Weighted-average assumptions used to determine net periodic cost: | |||
Discount rate | 2.52% | 3.30% | 4.24% |
Long-term rate of return | 6.61% | 6.75% | 6.72% |
Pension Plans and Other Postr_6
Pension Plans and Other Postretirement Benefits (Details-4) $ in Thousands | 12 Months Ended | |||
Dec. 31, 2021USD ($)Concentration | Dec. 31, 2020USD ($) | Dec. 31, 2019USD ($) | ||
Other postretirement benefits [Abstract] | ||||
Fair value of plan assets | $ 528,797 | $ 481,273 | ||
Pension Benefits [Member] | ||||
Defined Benefit Plan, Information about Plan Assets [Abstract] | ||||
Target Plan Asset Allocation | 100.00% | |||
Actual Plan Asset Allocation | 100.00% | 100.00% | ||
Other postretirement benefits [Abstract] | ||||
Fair value of plan assets | $ 473,953 | $ 429,538 | $ 386,033 | |
Pension Benefits [Member] | Plan Assets [Member] | Product Concentration Risk [Member] | ||||
Concentration of Credit Risk [Abstract] | ||||
Concentration risk, percentage | 10.00% | |||
Concentration risk, number of significant concentrations | Concentration | 0 | |||
Pension Benefits [Member] | Equity Securities [Member] | ||||
Defined Benefit Plan, Information about Plan Assets [Abstract] | ||||
Target Plan Asset Allocation | [1] | 63.00% | ||
Actual Plan Asset Allocation | [1] | 65.00% | 69.00% | |
Pension Benefits [Member] | United States Equity Securities [Member] | ||||
Defined Benefit Plan, Information about Plan Assets [Abstract] | ||||
Target Plan Asset Allocation | 45.50% | |||
Pension Benefits [Member] | Non-United States Equity Securities [Member] | ||||
Defined Benefit Plan, Information about Plan Assets [Abstract] | ||||
Target Plan Asset Allocation | 17.50% | |||
Pension Benefits [Member] | Fixed Income Securities [Member] | ||||
Defined Benefit Plan, Information about Plan Assets [Abstract] | ||||
Target Plan Asset Allocation | 30.00% | |||
Actual Plan Asset Allocation | 29.00% | 25.00% | ||
Pension Benefits [Member] | Real Estate [Member] | ||||
Defined Benefit Plan, Information about Plan Assets [Abstract] | ||||
Target Plan Asset Allocation | 7.00% | |||
Actual Plan Asset Allocation | 6.00% | 6.00% | ||
Postretirement Benefits [Member] | ||||
Other postretirement benefits [Abstract] | ||||
Fair value of plan assets | $ 54,844 | $ 51,735 | $ 48,889 | |
Master Pension Trust [Member] | ||||
Other postretirement benefits [Abstract] | ||||
Fair value of plan assets | $ 48,700 | $ 45,600 | ||
[1] | Target allocations for equity securities are broken out as follows: 45.5 % United States equity and 17.5 % non-United States equity. |
Pension Plans and Other Postr_7
Pension Plans and Other Postretirement Benefits (Details-5) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 |
Defined Benefit Plan Disclosure [Line Items] | ||
Fair value of plan assets | $ 528,797 | $ 481,273 |
Cash and Cash Equivalents [Member] | Level 1 [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Fair value of plan assets | 1,428 | 1,180 |
Equity Securities [Member] | U.S. Large Cap [Member] | Fair Value Measured At Net Asset Value | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Fair value of plan assets | 162,060 | 151,218 |
Equity Securities [Member] | U.S. Mid Cap [Member] | Fair Value Measured At Net Asset Value | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Fair value of plan assets | 38,755 | 37,389 |
Equity Securities [Member] | U.S. Small Cap [Member] | Fair Value Measured At Net Asset Value | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Fair value of plan assets | 47,657 | 50,456 |
Equity Securities [Member] | International Blend [Member] | Fair Value Measured At Net Asset Value | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Fair value of plan assets | 87,781 | 87,461 |
Fixed Income Securities [Member] | Short-Term Fund [Member] | Fair Value Measured At Net Asset Value | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Fair value of plan assets | 5,222 | 4,215 |
Fixed Income Securities [Member] | High Yield Bond [Member] | Fair Value Measured At Net Asset Value | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Fair value of plan assets | 25,190 | 22,683 |
Fixed Income Securities [Member] | Long Duration Bond [Member] | Fair Value Measured At Net Asset Value | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Fair value of plan assets | 119,867 | 92,657 |
Real Estate [Member] | Fair Value Measured At Net Asset Value | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Fair value of plan assets | 37,170 | 30,005 |
Insurance Continuance Fund [Member] | Fair Value Measured At Net Asset Value | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Fair value of plan assets | 1,599 | 1,506 |
Fixed Rate Fund [Member] | Fair Value Measured At Net Asset Value | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Fair value of plan assets | $ 2,068 | $ 2,503 |
Pension Plans and Other Postr_8
Pension Plans and Other Postretirement Benefits (Details-6) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Expected Cash Flows | |||
Expected employer contributions, 2022 | $ 0 | ||
Cash contributions to pension and other postretirement plans | 6,935 | $ 6,296 | $ 5,714 |
Pension Benefits [Member] | |||
Benefit Payments, Gross | |||
Defined benefit plan expected future benefit payments, 2022 | 19,736 | ||
Defined benefit plan expected future benefit payments, 2023 | 20,474 | ||
Defined benefit plan expected future benefit payments, 2024 | 21,197 | ||
Defined benefit plan expected future benefit payments, 2025 | 21,897 | ||
Defined benefit plan expected future benefit payments, 2026 | 22,497 | ||
Defined benefit plan expected future benefit payments, 2027-2031 | 117,862 | ||
Postretirement Benefits [Member] | |||
Benefit Payments, Gross | |||
Defined benefit plan expected future benefit payments, 2022 | 4,713 | ||
Defined benefit plan expected future benefit payments, 2023 | 4,982 | ||
Defined benefit plan expected future benefit payments, 2024 | 5,281 | ||
Defined benefit plan expected future benefit payments, 2025 | 5,533 | ||
Defined benefit plan expected future benefit payments, 2026 | 5,567 | ||
Defined benefit plan expected future benefit payments, 2027-2031 | 27,651 | ||
Medicare Part D Subsidies | |||
Expected Medicare Part D Subsidies, 2022 | (304) | ||
Expected Medicare Part D Subsidies, 2023 | (333) | ||
Expected Medicare Part D Subsidies, 2024 | (363) | ||
Expected Medicare Part D Subsidies, 2025 | (395) | ||
Expected Medicare Part D Subsidies, 2026 | (430) | ||
Expected Medicare Part D Subsidies, 2027-2031 | (2,541) | ||
Defined benefit plan expected net future benefit payments, 2022 | 4,409 | ||
Defined benefit plan expected net future benefit payments, 2023 | 4,649 | ||
Defined benefit plan expected net future benefit payments, 2024 | 4,918 | ||
Defined benefit plan expected net future benefit payments, 2025 | 5,138 | ||
Defined benefit plan expected net future benefit payments, 2026 | 5,137 | ||
Defined benefit plan expected net future benefit payments, 2027-2031 | $ 25,110 |
Share-Based Compensation (Detai
Share-Based Compensation (Details) - USD ($) $ / shares in Units, $ in Millions | Feb. 18, 2022 | Jan. 31, 2021 | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Compensation expense | $ 2.9 | $ 1.3 | $ 3 | |||
Restricted Stock Units Equity Awards [Member] | ||||||
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Nonvested [Roll Forward] | ||||||
Nonvested awards January 1, | 0 | 0 | ||||
Granted | 15,931,000 | 16,267,000 | ||||
Vested | 0 | |||||
Undistributed vested awards | [1] | 3,141,000 | ||||
Nonvested awards December 31, | 13,126,000 | 0 | ||||
Granted, weighted average grant date fair value | $ 65.83 | |||||
Undistributed vested awards, weighted average grant date fair value per share | [1] | 65.83 | ||||
Unvested, weighted average grant date fair value per share, ending balance | $ 65.83 | |||||
Restricted Stock Units Liability Awards [Member] | ||||||
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Nonvested [Roll Forward] | ||||||
Nonvested awards January 1, | 7,003,000 | 7,003,000 | ||||
Granted | 0 | |||||
Vested | 0 | |||||
Undistributed vested awards | [2] | 939,000 | ||||
Nonvested awards December 31, | 6,064,000 | 7,003,000 | ||||
Performance Units Liability Awards [Member] | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Award vesting period | 3 years | |||||
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Nonvested [Roll Forward] | ||||||
Nonvested awards January 1, | 7,003,000 | 7,003,000 | ||||
Granted | 10,395,000 | 10,187,000 | ||||
Vested | 0 | |||||
Undistributed vested awards | [3] | 3,320,000 | ||||
Nonvested awards December 31, | 13,870,000 | 7,003,000 | ||||
Weighted average fair Value of each nonvested award | $ 104.76 | |||||
Weighted average estimated payout percent based on performance criteria | 127.40% | |||||
Performance Units Liability Awards [Member] | Maximum [Member] | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Awards to be granted as percentage of target units | 200.00% | |||||
Performance Units Liability Awards [Member] | Minimum [Member] | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Awards to be granted as percentage of target units | 0.00% | |||||
2006 Performance Unit Plan [Member] | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Common stock to be issued with plan | 0 | |||||
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Nonvested [Roll Forward] | ||||||
Nonvested awards January 1, | 17,420,000 | 17,420,000 | ||||
Granted | 0 | |||||
Vested | (11,660,000) | |||||
Nonvested awards December 31, | 5,760,000 | 17,420,000 | ||||
2006 Performance Unit Plan [Member] | Performance Units [Member] | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Award vesting period | 5 years | |||||
2013 Director Incentive Agreement [Member] | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Common stock to be issued with plan | 0 | |||||
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Nonvested [Roll Forward] | ||||||
Nonvested awards January 1, | 4,286,000 | 4,286,000 | ||||
Granted | 0 | |||||
Vested | (2,814,000) | |||||
Nonvested awards December 31, | 1,472,000 | 4,286,000 | ||||
2013 Director Incentive Agreement [Member] | Performance Units [Member] | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Award vesting period | 3 years | |||||
2006 Performance Unit Plan and 2013 Director Incentive Plan [Member] | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Cash payments distributed related to awards previously granted and now payable | $ 1.9 | |||||
2021 Long Term Incentive Plan [Member] | Maximum [Member] | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Common stock to be issued with plan | 500,000,000 | |||||
[1] | Represents restricted stock units that vested but were not distributed to retirement-eligible employees during 2021. | |||||
[2] | Represents restricted stock units that vested but were not distributed to retirement-eligible employees during 2021. | |||||
[3] | Represents performance units that vested but were not distributed to retirement-eligible employees during 2021. |
Notes Payable to Banks, Comme_3
Notes Payable to Banks, Commercial Paper, and Lines of Credit (Details) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021USD ($) | Dec. 31, 2020USD ($) | ||
Short-term Debt [Line Items] | |||
Short-term debt outstanding | [1] | $ 5,500 | $ 52,500 |
Letters of credit issued inside credit facilities | [1] | $ 685 | $ 685 |
Weighted-average interest rate | [1] | 0.15% | 0.15% |
Maximum short-term borrowings | [1] | $ 64,000 | $ 52,500 |
Average short-term borrowings | [1] | $ 28,583 | $ 6,393 |
Weighted-average interest rate during the year | [1] | 0.15% | 0.43% |
Line of Credit [Member] | |||
Short-term Debt [Line Items] | |||
Available capacity under line of credit | [1] | $ 143,815 | $ 96,815 |
Line of Credit [Member] | MGE Energy unsecured committed revolving line of credit totaling $50 million [Member] | MGE Energy [Member] | |||
Short-term Debt [Line Items] | |||
Line of credit | 50,000 | ||
Line of credit, borrowings outstanding | $ 0 | ||
Debt covenant, required parent company ownership of MGE | 100.00% | ||
Line of Credit [Member] | MGE Energy unsecured committed revolving line of credit totaling $50 million [Member] | Minimum [Member] | MGE Energy [Member] | |||
Short-term Debt [Line Items] | |||
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value | 30.00% | ||
Line of Credit [Member] | MGE Energy unsecured committed revolving line of credit totaling $50 million [Member] | Maximum [Member] | MGE Energy [Member] | |||
Short-term Debt [Line Items] | |||
Debt to total capitalization ratio | 0.65 | ||
MGE [Member] | |||
Short-term Debt [Line Items] | |||
Short-term debt outstanding | $ 5,500 | 52,500 | |
Letters of credit issued inside credit facilities | $ 685 | $ 685 | |
Weighted-average interest rate | 0.15% | 0.15% | |
Maximum short-term borrowings | $ 64,000 | $ 52,500 | |
Average short-term borrowings | $ 28,583 | $ 6,393 | |
Weighted-average interest rate during the year | 0.15% | 0.43% | |
MGE [Member] | Line of Credit [Member] | |||
Short-term Debt [Line Items] | |||
Available capacity under line of credit | $ 93,815 | $ 46,815 | |
MGE [Member] | Line of Credit [Member] | MGE unsecured committed revolving lines of credit totaling $100 million [Member] | |||
Short-term Debt [Line Items] | |||
Line of credit | 100,000 | ||
Line of credit, borrowings outstanding | $ 0 | ||
Debt covenant, required parent company ownership of MGE | 100.00% | ||
MGE [Member] | Line of Credit [Member] | MGE unsecured committed revolving lines of credit totaling $100 million [Member] | Minimum [Member] | |||
Short-term Debt [Line Items] | |||
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value | 30.00% | ||
MGE [Member] | Line of Credit [Member] | MGE unsecured committed revolving lines of credit totaling $100 million [Member] | Maximum [Member] | |||
Short-term Debt [Line Items] | |||
Debt to total capitalization ratio | 0.65 | ||
[1] | MGE Energy short-term borrowings include MGE Energy and MGE lines of credit and MGE commercial paper. |
Long-Term Debt (Details-1)
Long-Term Debt (Details-1) - USD ($) $ in Thousands | 12 Months Ended | |||
Dec. 31, 2021 | Dec. 31, 2020 | |||
Debt Instrument [Line Items] | ||||
Long-term debt due within one year | $ (4,889) | $ (4,771) | ||
Unamortized discount and debt issuance costs | (4,349) | (4,146) | ||
Total Long-Term Debt | 614,211 | 519,303 | ||
First Mortgage Bonds [Member] | 7.70%, 2028 Series [Member] | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [1] | $ 1,200 | $ 1,200 | |
Interest rate | 7.70% | 7.70% | ||
Debt covenant, allowable amount available for payment of dividends | $ 604,300 | |||
Tax Exempt Debt [Member] | 2.05%, 2023 Series, Industrial Development Revenue Bonds | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | $ 19,300 | $ 19,300 | ||
Interest rate | 2.05% | 2.05% | ||
Medium-Term Notes [Member] | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | $ 70,000 | $ 70,000 | ||
Medium-Term Notes [Member] | 6.12%, due 2028 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [2] | $ 20,000 | $ 20,000 | |
Interest rate | 6.12% | 6.12% | ||
Medium-Term Notes [Member] | 7.12%, due 2032 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [2] | $ 25,000 | $ 25,000 | |
Interest rate | 7.12% | 7.12% | ||
Medium-Term Notes [Member] | 6.247%, due 2037 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [2] | $ 25,000 | $ 25,000 | |
Interest rate | 6.247% | 6.247% | ||
Other Long-Term Debt [Member] | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | $ 532,949 | $ 437,720 | ||
Other Long-Term Debt [Member] | 3.09%, due 2023 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [3],[4] | $ 30,000 | $ 30,000 | |
Interest rate | 3.09% | 3.09% | ||
Other Long-Term Debt [Member] | 3.09%, due 2023 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value | 30.00% | |||
Other Long-Term Debt [Member] | 3.09%, due 2023 | Maximum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt to total capitalization ratio | 0.65 | |||
Priority debt to assets ratio | 0.20 | |||
Other Long-Term Debt [Member] | 3.29%, due 2026 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [3],[4] | $ 15,000 | $ 15,000 | |
Interest rate | 3.29% | 3.29% | ||
Other Long-Term Debt [Member] | 3.29%, due 2026 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value | 30.00% | |||
Other Long-Term Debt [Member] | 3.29%, due 2026 | Maximum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt to total capitalization ratio | 0.65 | |||
Priority debt to assets ratio | 0.20 | |||
Other Long-Term Debt [Member] | 3.11% due 2027 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [3],[4] | $ 30,000 | $ 30,000 | |
Interest rate | 3.11% | 3.11% | ||
Other Long-Term Debt [Member] | 3.11% due 2027 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value | 30.00% | |||
Other Long-Term Debt [Member] | 3.11% due 2027 | Maximum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt to total capitalization ratio | 0.65 | |||
Priority debt to assets ratio | 0.20 | |||
Other Long-Term Debt [Member] | 2.94% due 2029 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [3],[4] | $ 50,000 | $ 50,000 | |
Interest rate | 2.94% | 2.94% | ||
Other Long-Term Debt [Member] | 2.94% due 2029 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value | 30.00% | |||
Other Long-Term Debt [Member] | 2.94% due 2029 | Maximum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt to total capitalization ratio | 0.65 | |||
Priority debt to assets ratio | 0.20 | |||
Other Long-Term Debt [Member] | 2.48%, due 2031 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | $ 60,000 | [3],[4],[5] | $ 0 | |
Interest rate | 2.48% | |||
Other Long-Term Debt [Member] | 2.48%, due 2031 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value | 30.00% | |||
Other Long-Term Debt [Member] | 2.48%, due 2031 | Maximum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt to total capitalization ratio | 0.65 | |||
Priority debt to assets ratio | 0.20 | |||
Other Long-Term Debt [Member] | 5.68%, due 2033 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [4],[6] | $ 21,510 | $ 22,762 | |
Interest rate | 5.68% | 5.68% | ||
Other Long-Term Debt [Member] | 5.19%, due 2033 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [4],[6] | $ 14,133 | $ 14,985 | |
Interest rate | 5.19% | 5.19% | ||
Other Long-Term Debt [Member] | 2.63%, due 2033 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | $ 40,000 | [2],[5] | $ 0 | |
Interest rate | 2.63% | |||
Other Long-Term Debt [Member] | 2.63%, due 2033 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value | 30.00% | |||
Other Long-Term Debt [Member] | 2.63%, due 2033 | Maximum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt to total capitalization ratio | 0.65 | |||
Priority debt to assets ratio | 0.20 | |||
Other Long-Term Debt [Member] | 5.26%, due 2040 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [3],[4] | $ 15,000 | $ 15,000 | |
Interest rate | 5.26% | 5.26% | ||
Other Long-Term Debt [Member] | 5.26%, due 2040 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value | 30.00% | |||
Other Long-Term Debt [Member] | 5.26%, due 2040 | Maximum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt to total capitalization ratio | 0.65 | |||
Priority debt to assets ratio | 0.20 | |||
Other Long-Term Debt [Member] | 5.04%, due 2040 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [4],[7] | $ 30,139 | $ 31,806 | |
Interest rate | 5.04% | 5.04% | ||
Other Long-Term Debt [Member] | 4.74%, due 2041 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [4],[7] | $ 19,167 | $ 20,167 | |
Interest rate | 4.74% | 4.74% | ||
Other Long-Term Debt [Member] | 4.38%, due 2042 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [3],[4] | $ 28,000 | $ 28,000 | |
Interest rate | 4.38% | 4.38% | ||
Other Long-Term Debt [Member] | 4.38%, due 2042 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value | 30.00% | |||
Other Long-Term Debt [Member] | 4.38%, due 2042 | Maximum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt to total capitalization ratio | 0.65 | |||
Priority debt to assets ratio | 0.20 | |||
Other Long-Term Debt [Member] | 4.42%, due 2043 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [3],[4] | $ 20,000 | $ 20,000 | |
Interest rate | 4.42% | 4.42% | ||
Other Long-Term Debt [Member] | 4.42%, due 2043 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value | 30.00% | |||
Other Long-Term Debt [Member] | 4.42%, due 2043 | Maximum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt to total capitalization ratio | 0.65 | |||
Priority debt to assets ratio | 0.20 | |||
Other Long-Term Debt [Member] | 4.47%, due 2048 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [3],[4] | $ 20,000 | $ 20,000 | |
Interest rate | 4.47% | 4.47% | ||
Other Long-Term Debt [Member] | 4.47%, due 2048 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value | 30.00% | |||
Other Long-Term Debt [Member] | 4.47%, due 2048 | Maximum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt to total capitalization ratio | 0.65 | |||
Priority debt to assets ratio | 0.20 | |||
Other Long-Term Debt [Member] | 3.76% due 2052 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [3],[4] | $ 40,000 | $ 40,000 | |
Interest rate | 3.76% | 3.76% | ||
Other Long-Term Debt [Member] | 3.76% due 2052 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value | 30.00% | |||
Other Long-Term Debt [Member] | 3.76% due 2052 | Maximum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt to total capitalization ratio | 0.65 | |||
Priority debt to assets ratio | 0.20 | |||
Other Long-Term Debt [Member] | 4.19% due 2048 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [3],[4] | $ 60,000 | $ 60,000 | |
Interest rate | 4.19% | 4.19% | ||
Other Long-Term Debt [Member] | 4.19% due 2048 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value | 30.00% | |||
Other Long-Term Debt [Member] | 4.19% due 2048 | Maximum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt to total capitalization ratio | 0.65 | |||
Priority debt to assets ratio | 0.20 | |||
Other Long-Term Debt [Member] | 4.24% due 2053 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [3],[4] | $ 20,000 | $ 20,000 | |
Interest rate | 4.24% | 4.24% | ||
Other Long-Term Debt [Member] | 4.24% due 2053 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value | 30.00% | |||
Other Long-Term Debt [Member] | 4.24% due 2053 | Maximum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt to total capitalization ratio | 0.65 | |||
Priority debt to assets ratio | 0.20 | |||
Other Long-Term Debt [Member] | 4.34% due 2058 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt, gross | [3],[4] | $ 20,000 | $ 20,000 | |
Interest rate | 4.34% | 4.34% | ||
Other Long-Term Debt [Member] | 4.34% due 2058 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value | 30.00% | |||
Other Long-Term Debt [Member] | 4.34% due 2058 | Maximum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt to total capitalization ratio | 0.65 | |||
Priority debt to assets ratio | 0.20 | |||
MGE Power Elm Road [Member] | ||||
Debt Instrument [Line Items] | ||||
Unamortized discount and debt issuance costs | $ (300) | $ (400) | ||
MGE Power Elm Road [Member] | Other Long-Term Debt [Member] | 5.04%, due 2040 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt service coverage ratio | 1.25 | |||
MGE Power Elm Road [Member] | Other Long-Term Debt [Member] | 4.74%, due 2041 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt service coverage ratio | 1.25 | |||
MGE Power West Campus [Member] | ||||
Debt Instrument [Line Items] | ||||
Unamortized discount and debt issuance costs | $ (100) | $ (100) | ||
MGE Power West Campus [Member] | Other Long-Term Debt [Member] | 5.68%, due 2033 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt service coverage ratio | 1.25 | |||
MGE Power West Campus [Member] | Other Long-Term Debt [Member] | 5.68%, due 2033 | Maximum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt to total capitalization ratio | 0.65 | |||
MGE Power West Campus [Member] | Other Long-Term Debt [Member] | 5.19%, due 2033 | Minimum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt service coverage ratio | 1.25 | |||
MGE Power West Campus [Member] | Other Long-Term Debt [Member] | 5.19%, due 2033 | Maximum [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt to total capitalization ratio | 0.65 | |||
[1] | MGE's utility plant is subject to the lien of its Indenture of Mortgage and Deed of Trust, under which its first mortgage bonds are issued. The Mortgage Indenture provides that dividends or any other distribution or purchase of MGE shares may not be made if the aggregate amount thereof since December 31, 1945, would exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2021, approximately $ 604.3 million was available for the payment of dividends under this covenant. | |||
[2] | The indenture under which MGE's Medium-Term notes are issued provides that those notes will be entitled to be equally and ratably secured in the event that MGE issues any additional first mortgage bonds. | |||
[3] | Issued by MGE. Under that Note Purchase Agreement: (i) note holders have the right to require MGE to repurchase their notes at par in the event of an acquisition of beneficial ownership of 30 % or more of the outstanding voting stock of MGE Energy, (ii) MGE must maintain a ratio of its consolidated indebtedness to consolidated total capitalization not to exceed a maximum of 65 %, and (iii) MGE cannot issue "Priority Debt" in an amount exceeding 20 % of its consolidated assets. Priority Debt is defined as any indebtedness of MGE secured by liens other than specified liens permitted by the Note Purchase Agreement and certain unsecured indebtedness of certain subsidiaries. As of December 31, 2021 , MGE was in compliance with the covenant requirements. | |||
[4] | Unsecured notes issued pursuant to various Note Purchase Agreements with one or more purchasers. The notes are not issued under, or governed by, MGE's Indenture dated as of September 1, 1998, which governs MGE's Medium-Term Notes. | |||
[5] | In May 2021, MGE entered into a private placement Note Purchase Agreement in which it committed to issue $60 million of new long-term debt (Series A) and $40 million of new long-term debt (Series B). Funding occurred on June 15, 2021, for Series B and August 27, 2021, for Series A. The proceeds of the debt financing were used to assist with capital expenditures and other corporate obligations. | |||
[6] | Issued by MGE Power West Campus. The Note Purchase Agreements require MGE Power West Campus to maintain a projected debt service coverage ratio of not less than 1.25 to 1.00, and debt to total capitalization ratio of not more than 0.65 to 1.00. The notes are secured by a collateral assignment of lease payments that MGE is making to MGE Power West Campus for use of the WCCF pursuant to a long-term lease. As of December 31, 2021 , MGE Power West Campus was in compliance with the covenant requirements. | |||
[7] | Issued by MGE Power Elm Road. The Note Purchase Agreement requires MGE Power Elm Road to maintain a projected and actual debt service coverage ratio at the end of any calendar quarter of not less than 1.25 to 1.00 for the trailing 12-month period. The notes are secured by a collateral assignment of lease payments that MGE is making to MGE Power Elm Road for use of the Elm Road Units pursuant to long-term leases. As of December 31, 2021 , MGE Power Elm Road was in compliance with the covenant requirements. |
Long-Term Debt (Details-2)
Long-Term Debt (Details-2) $ in Thousands | Dec. 31, 2021USD ($) |
Long-Term Debt Maturities [Abstract] | |
Long term debt maturities in 2022 | $ 4,889 |
Long term debt maturities in 2023 | 54,314 |
Long term debt maturities in 2024 | 5,146 |
Long term debt maturities in 2025 | 5,285 |
Long term debt maturities in 2026 | 20,433 |
Long term debt maturities in future years | $ 533,382 |
Common Equity (Details)
Common Equity (Details) | 12 Months Ended | ||
Dec. 31, 2021USD ($)$ / sharesshares | Dec. 31, 2020USD ($)$ / sharesshares | Dec. 31, 2019USD ($)$ / shares | |
Class of Stock [Line Items] | |||
Common stock dividends declared | $ 54,788,000 | $ 51,729,000 | $ 47,842,000 |
Common stock dividends declared (in dollars per share) | $ / shares | $ 1.52 | $ 1.45 | $ 1.38 |
Common stock issued during period | shares | 1,500,000 | ||
Common stock issued during period under the stock plan | shares | 0 | 0 | |
Proceeds From Issuance Of Common Stock | $ 0 | $ 79,635,000 | $ 0 |
Dilutive Securities | 3,668,000 | ||
MGE [Member] | |||
Class of Stock [Line Items] | |||
Cash dividends paid to parent by MGE | $ 5,000,000 | $ 0 | |
MGE [Member] | Minimum [Member] | |||
Class of Stock [Line Items] | |||
Dividend restrictions, common equity ratio | 0.55 |
Commitments and Contingencies_2
Commitments and Contingencies (Details-1) $ in Millions | Dec. 31, 2021USD ($) |
Columbia Units [Member] | |
Public Utilities, General Disclosures [Line Items] | |
Projected costs for enviornmental regulations | $ 4 |
Elm Road Units [Member] | |
Public Utilities, General Disclosures [Line Items] | |
Projected costs for enviornmental regulations | $ 4 |
Commitments and Contingencies_3
Commitments and Contingencies (Details-2) $ in Thousands | Dec. 31, 2021USD ($) | |
Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
Purchase obligation due in next twelve months | $ 100,469 | |
Purchase obligation due in second year | 43,640 | |
Purchase obligation due in third year | 35,067 | |
Purchase obligation due in fourth year | 30,944 | |
Purchase obligation due in fifth year | 19,980 | |
Purchase obligation due thereafter | 43,922 | |
Coal [Member] | ||
Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
Purchase obligation due in next twelve months | 20,662 | [1] |
Purchase obligation due in second year | 11,752 | [1] |
Purchase obligation due in third year | 4,394 | [1] |
Purchase obligation due in fourth year | 937 | [1] |
Purchase obligation due in fifth year | 0 | [1] |
Purchase obligation due thereafter | 0 | [1] |
Natural Gas, Transportation and Storage [Member] | ||
Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
Purchase obligation due in next twelve months | 23,307 | [2] |
Purchase obligation due in second year | 23,922 | [2] |
Purchase obligation due in third year | 23,922 | [2] |
Purchase obligation due in fourth year | 23,922 | [2] |
Purchase obligation due in fifth year | 13,772 | [2] |
Purchase obligation due thereafter | 11,525 | [2] |
Natural Gas, Supply [Member] | ||
Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
Purchase obligation due in next twelve months | 26,987 | [3] |
Purchase obligation due in second year | 0 | [3] |
Purchase obligation due in third year | 0 | [3] |
Purchase obligation due in fourth year | 0 | [3] |
Purchase obligation due in fifth year | 0 | [3] |
Purchase obligation due thereafter | 0 | [3] |
Purchased Power [Member] | ||
Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
Purchase obligation due in next twelve months | 14,249 | [4] |
Purchase obligation due in second year | 5,061 | [4] |
Purchase obligation due in third year | 5,162 | [4] |
Purchase obligation due in fourth year | 5,266 | [4] |
Purchase obligation due in fifth year | 5,371 | [4] |
Purchase obligation due thereafter | 5,723 | [4] |
Renewable energy [Member] | ||
Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
Purchase obligation due in next twelve months | 7,999 | [5] |
Purchase obligation due in second year | 1,185 | [5] |
Purchase obligation due in third year | 698 | [5] |
Purchase obligation due in fourth year | 714 | [5] |
Purchase obligation due in fifth year | 730 | [5] |
Purchase obligation due thereafter | 25,876 | [5] |
Other [Member] | ||
Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
Purchase obligation due in next twelve months | 7,265 | |
Purchase obligation due in second year | 1,720 | |
Purchase obligation due in third year | 891 | |
Purchase obligation due in fourth year | 105 | |
Purchase obligation due in fifth year | 107 | |
Purchase obligation due thereafter | $ 798 | |
[1] | Total coal commitments for the Columbia and Elm Road Units, including transportation. Fuel procurement for MGE's jointly owned Columbia and Elm Road Units is handled by WPL and WEPCO, respectively, who are the operators of those facilities. | |
[2] | MGE's natural gas transportation and storage contracts require fixed monthly payments for firm supply pipeline transportation and storage capacity. The pricing components of the fixed monthly payments for the transportation and storage contracts are approved by FERC but may be subject to change. | |
[3] | These commitments include market-based pricing. | |
[4] | MGE has several purchase power agreements to help meet future electric supply requirements. | |
[5] | Operational commitments for solar and wind facilities. |
Commitments and Contingencies_4
Commitments and Contingencies (Details-3) $ in Thousands | 12 Months Ended |
Dec. 31, 2021USD ($) | |
Other Commitments [Line Items] | |
2022 | $ 333 |
2023 | 333 |
2024 | 333 |
2025 | 333 |
2026 | 333 |
Thereafter | 2,666 |
Investments in Non Public Entities, Capital Infusions [Member] | |
Other Commitments [Line Items] | |
Other commitment, initial agreed upon commitment total | $ 10,000 |
Venture Debt Fund [Member] | |
Other Commitments [Line Items] | |
Other commitment, contract term, expiring in 2022 | 3 years |
Other commitment, initial agreed upon commitment total | $ 1,500 |
Other commitments, total as of balance sheet date | $ 700 |
Asset Retirement Obligations (D
Asset Retirement Obligations (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | ||
Asset Retirement Obligations [Roll Forward] | |||
Asset retirement obligation, beginning balance | $ 31,196 | $ 28,355 | |
Liabilities incurred | [1] | 8,589 | 3,503 |
Accretion expense | 1,526 | 1,366 | |
Liabilities settled | (354) | (372) | |
Revisions in estimated cash flows | [2] | 5,623 | (1,656) |
Asset retirement obligation, ending balance | 46,580 | 31,196 | |
Two Creeks [Member] | |||
Asset Retirement Obligations [Roll Forward] | |||
Liabilities incurred | 3,200 | ||
Badger Hollow [Member] | |||
Asset Retirement Obligations [Roll Forward] | |||
Liabilities incurred | $ 4,900 | $ 3,400 | |
[1] | In 2021, MGE recorded an obligation of $ 4.9 million and $ 3.4 million, respectively, for the fair value of its legal liability for AROs associated with Badger Hollow I and other completed renewable projects. In 2020, MGE recorded an obligation of $ 3.2 million for the fair value of its legal liability for AROs associated with Two Creeks. See Footnote 6 for additional information on Badger Hollow I and Two Creeks . | ||
[2] | In 2021, MGE revised the AROs associated with certain Columbia assets. |
Derivative and Hedging Instru_3
Derivative and Hedging Instruments (Details-1) $ in Thousands | 12 Months Ended | ||||
Dec. 31, 2021USD ($)Dth1MWhMW | Dec. 31, 2020USD ($)Dth1MWhMW | Dec. 31, 2019USD ($) | |||
Other Current Assets [Member] | |||||
Derivative Fair Values [Abstract] | |||||
Derivative fair value, net | $ 770 | $ 1,162 | $ 1,100 | ||
Commodity Contracts and Financial Transimission Rights [Member] | |||||
Derivative Fair Values [Abstract] | |||||
Derivative fair value, net | $ 2,800 | $ 200 | |||
Commodity Derivative Contracts [Member] | |||||
Gross Notional Volume of Open Derivatives | |||||
Notional amount, energy measure (in MWh) | MWh | 278,000 | 259,080 | |||
Notional amount, decatherm measure (in Dth) | Dth1 | 5,735,000 | 6,030,000 | |||
Derivative Fair Values [Abstract] | |||||
Asset Derivatives, fair value, gross basis | $ 3,379 | $ 806 | |||
Liability Derivatives, fair value, gross basis | 849 | 632 | |||
Collateral posted against derivative positions | 0 | 0 | |||
Commodity Derivative Contracts [Member] | Other Current Assets [Member] | |||||
Derivative Fair Values [Abstract] | |||||
Asset Derivatives, fair value, gross basis | 2,959 | [1] | 617 | [2] | |
Liability Derivatives, fair value, gross basis | 811 | [1] | 593 | [2] | |
Commodity Derivative Contracts [Member] | Other Deferred Charges [Member] | |||||
Derivative Fair Values [Abstract] | |||||
Asset Derivatives, fair value, gross basis | 420 | [1] | 189 | [2] | |
Liability Derivatives, fair value, gross basis | 38 | [1] | 39 | [2] | |
Commodity Derivative Contracts [Member] | Cash Flow Hedging [Member] | |||||
Derivative Fair Values [Abstract] | |||||
Collateral posted against derivative positions | $ 1,300 | $ 0 | |||
Financial Transmission Rights [Member] | |||||
Gross Notional Volume of Open Derivatives | |||||
Notional amount, power measure (in MW) | MW | 2,127 | 2,869 | |||
Derivative Fair Values [Abstract] | |||||
Asset Derivatives, fair value, gross basis | $ 227 | ||||
Liability Derivatives, fair value, gross basis | $ 23 | ||||
Collateral posted against derivative positions | 0 | ||||
Financial Transmission Rights [Member] | Other Current Assets [Member] | |||||
Derivative Fair Values [Abstract] | |||||
Asset Derivatives, fair value, gross basis | 227 | ||||
Liability Derivatives, fair value, gross basis | $ 0 | ||||
Financial Transmission Rights [Member] | Other Current Liabilities [Member] | |||||
Derivative Fair Values [Abstract] | |||||
Asset Derivatives, fair value, gross basis | 0 | ||||
Liability Derivatives, fair value, gross basis | $ 23 | ||||
Energy Related Commodity Contract [Member] | Cash Flow Hedging [Member] | |||||
Derivatives Fair Value [Line Items] | |||||
Maximum term of derivative hedging contract | 4 years | ||||
PPA [Member] | |||||
Gross Notional Volume of Open Derivatives | |||||
Notional amount, power measure (in MW) | MW | 250 | 850 | |||
Derivative Fair Values [Abstract] | |||||
Derivative fair value, net | $ (2,100) | $ (14,100) | |||
Liability Derivatives, fair value, gross basis | 2,140 | 14,140 | |||
Collateral posted against derivative positions | 0 | 0 | |||
PPA [Member] | Derivative Liability (Current) [Member] | |||||
Derivative Fair Values [Abstract] | |||||
Liability Derivatives, fair value, gross basis | $ 2,140 | 10,160 | |||
PPA [Member] | Derivative Liability (Long-term) [Member] | |||||
Derivative Fair Values [Abstract] | |||||
Liability Derivatives, fair value, gross basis | $ 3,980 | ||||
[1] | As of December 31, 2021, MGE received collateral of $ 1.3 million from counterparties under a master netting agreement for outstanding exchange traded derivative positions. The fair value of the derivative asset disclosed in this table has not been reduced for the collateral received. | ||||
[2] | No collateral was posted against derivative positions as of December 31, 2020 . |
Derivative and Hedging Instru_4
Derivative and Hedging Instruments (Details-2) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 |
Offsetting Assets [Line Items] | ||
Collateral posted against derivative positions | $ (1,300) | $ 0 |
Commodity Derivative Contracts [Member] | ||
Offsetting Assets [Line Items] | ||
Gross amounts | 3,379 | 806 |
Gross amounts offset in balance sheet | (849) | (632) |
Collateral posted against derivative positions | (1,254) | 0 |
Net amount presented in balance sheet | 1,276 | $ 174 |
Financial Transmission Rights [Member] | ||
Offsetting Assets [Line Items] | ||
Gross amounts | 227 | |
Gross amounts offset in balance sheet | 0 | |
Collateral posted against derivative positions | 0 | |
Net amount presented in balance sheet | $ 227 |
Derivative and Hedging Instru_5
Derivative and Hedging Instruments (Details-3) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 |
Commodity Derivative Contracts [Member] | ||
Offsetting Liabilities [Line Items] | ||
Gross amounts | $ 849 | $ 632 |
Gross amounts offset in balance sheet | (849) | (632) |
Collateral posted against derivative positions | 0 | 0 |
Net amount presented in the balance sheet | 0 | 0 |
Financial Transmission Rights [Member] | ||
Offsetting Liabilities [Line Items] | ||
Gross amounts | 23 | |
Gross amounts offset in balance sheet | 0 | |
Collateral posted against derivative positions | 0 | |
Net amount presented in the balance sheet | 23 | |
Purchased Power Agreement [Member] | ||
Offsetting Liabilities [Line Items] | ||
Gross amounts | 2,140 | 14,140 |
Gross amounts offset in balance sheet | 0 | |
Collateral posted against derivative positions | 0 | 0 |
Net amount presented in the balance sheet | $ 2,140 | $ 14,140 |
Derivative and Hedging Instru_6
Derivative and Hedging Instruments (Details-4) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2021 | Dec. 31, 2020 | |
Current and Long-Term Regulatory Asset [Member] | ||
Change in Derivative Fair Value [Roll Forward] | ||
Beginning balance | $ 13,989 | $ 26,875 |
Unrealized gain | (23,173) | (4,895) |
Realized (loss) gain reclassified to a deferred account | 2,563 | (2,232) |
Realized (loss) gain reclassified to income statement | 6,004 | (5,759) |
Ending balance | (617) | 13,989 |
Other Current Assets [Member] | ||
Change in Derivative Fair Value [Roll Forward] | ||
Beginning balance | 1,162 | 1,100 |
Unrealized gain | ||
Realized (loss) gain reclassified to a deferred account | (2,563) | 2,232 |
Realized (loss) gain reclassified to income statement | 2,171 | (2,170) |
Ending balance | $ 770 | $ 1,162 |
Derivative and Hedging Instru_7
Derivative and Hedging Instruments (Details-5) $ in Thousands | 12 Months Ended | |
Dec. 31, 2021USD ($)Counterparty | Dec. 31, 2020USD ($) | |
Counterparties in net liability position or default [Abstract] | ||
Derivative, net liability position of counterparties | $ 0 | $ 0 |
Number of counterparties in default | Counterparty | 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 | $ (3,948) | 2,566 |
Commodity Derivative Contracts [Member] | Cost Of Gas Sold Expense [Member] | ||
Realized losses (gains) on income statement [Line Items] | ||
Realized losses (gains) on income statement | (1,700) | 1,729 |
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 | (605) | 63 |
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 |
Purchased Power Agreement [Member] | ||
Derivative collateral required to be posted for ten-year PPA [Abstract] | ||
Minimum collateral that may be required to be posted | 20,000 | |
Maximum collateral that may be required to be posted | 40,000 | |
Collateral posted | 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 | (1,922) | 3,571 |
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 |
Fair Value of Financial Instr_3
Fair Value of Financial Instruments (Details-1) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 | |
Liabilities: | |||
Unamortized discount and debt issuance costs | $ 4,349 | $ 4,146 | |
Carrying Amount [Member] | |||
Assets: | |||
Cash and cash equivalents | 17,438 | 44,738 | |
Liabilities: | |||
Short-term debt - commercial paper | 5,500 | 52,500 | |
Long-Term debt | [1] | 623,449 | 528,220 |
Fair Value [Member] | |||
Assets: | |||
Cash and cash equivalents | 17,438 | 44,738 | |
Liabilities: | |||
Short-term debt - commercial paper | 5,500 | 52,500 | |
Long-Term debt | [1] | 729,914 | 639,271 |
MGE [Member] | |||
Liabilities: | |||
Unamortized discount and debt issuance costs | 4,300 | 4,100 | |
MGE [Member] | Carrying Amount [Member] | |||
Assets: | |||
Cash and cash equivalents | 6,401 | 4,103 | |
Liabilities: | |||
Short-term debt - commercial paper | 5,500 | 52,500 | |
Long-Term debt | [1] | 623,449 | 528,220 |
MGE [Member] | Fair Value [Member] | |||
Assets: | |||
Cash and cash equivalents | 6,401 | 4,103 | |
Liabilities: | |||
Short-term debt - commercial paper | 5,500 | 52,500 | |
Long-Term debt | [1] | $ 729,914 | $ 639,271 |
[1] | Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $ 4.3 million and $ 4.1 million as of December 31, 2021 and 2020 , respectively. |
Fair Value of Financial Instr_4
Fair Value of Financial Instruments (Details-2) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 | |
Assets: | |||
Derivative asset, collateral offset | $ 1,300 | $ 0 | |
Recurring [Member] | |||
Assets: | |||
Derivative assets, net | [1] | 3,606 | 806 |
Exchange-traded investments | 1,296 | 1,750 | |
Total Assets | 4,902 | 2,556 | |
Liabilities: | |||
Derivative liabilities, net | [1] | 2,989 | 14,795 |
Deferred compensation | 3,653 | 3,509 | |
Total Liabilities | 6,642 | 18,304 | |
Recurring [Member] | Level 1 [Member] | |||
Assets: | |||
Derivative assets, net | [1] | 1,170 | 436 |
Exchange-traded investments | 1,296 | 1,750 | |
Total Assets | 2,466 | 2,186 | |
Liabilities: | |||
Derivative liabilities, net | [1] | 731 | 370 |
Deferred compensation | 0 | 0 | |
Total Liabilities | 731 | 370 | |
Recurring [Member] | Level 2 [Member] | |||
Assets: | |||
Derivative assets, net | [1] | 0 | 0 |
Exchange-traded investments | 0 | 0 | |
Total Assets | 0 | 0 | |
Liabilities: | |||
Derivative liabilities, net | [1] | 0 | 0 |
Deferred compensation | 3,653 | 3,509 | |
Total Liabilities | 3,653 | 3,509 | |
Recurring [Member] | Level 3 [Member] | |||
Assets: | |||
Derivative assets, net | [1] | 2,436 | 370 |
Exchange-traded investments | 0 | 0 | |
Total Assets | 2,436 | 370 | |
Liabilities: | |||
Derivative liabilities, net | [1] | 2,258 | 14,425 |
Deferred compensation | 0 | 0 | |
Total Liabilities | 2,258 | 14,425 | |
MGE [Member] | Recurring [Member] | |||
Assets: | |||
Derivative assets, net | [1] | 3,606 | 806 |
Exchange-traded investments | 230 | 603 | |
Total Assets | 3,836 | 1,409 | |
Liabilities: | |||
Derivative liabilities, net | [1] | 2,989 | 14,795 |
Deferred compensation | 3,653 | 3,509 | |
Total Liabilities | 6,642 | 18,304 | |
MGE [Member] | Recurring [Member] | Level 1 [Member] | |||
Assets: | |||
Derivative assets, net | [1] | 1,170 | 436 |
Exchange-traded investments | 230 | 603 | |
Total Assets | 1,400 | 1,039 | |
Liabilities: | |||
Derivative liabilities, net | [1] | 731 | 370 |
Deferred compensation | 0 | 0 | |
Total Liabilities | 731 | 370 | |
MGE [Member] | Recurring [Member] | Level 2 [Member] | |||
Assets: | |||
Derivative assets, net | [1] | 0 | 0 |
Exchange-traded investments | 0 | ||
Total Assets | 0 | 0 | |
Liabilities: | |||
Derivative liabilities, net | [1] | 0 | 0 |
Deferred compensation | 3,653 | 3,509 | |
Total Liabilities | 3,653 | 3,509 | |
MGE [Member] | Recurring [Member] | Level 3 [Member] | |||
Assets: | |||
Derivative assets, net | [1] | 2,436 | 370 |
Exchange-traded investments | 0 | 0 | |
Total Assets | 2,436 | 370 | |
Liabilities: | |||
Derivative liabilities, net | [1] | 2,258 | 14,425 |
Deferred compensation | 0 | 0 | |
Total Liabilities | $ 2,258 | $ 14,425 | |
[1] | As of December 31, 2021 , MGE received collateral of $ 1.3 million from counterparties under a master netting agreement for outstanding exchange traded derivative positions. The fair value of the derivative asset disclosed in this table has not been reduced for the collateral received. No collateral was posted against derivative positions owed to counterparties under a master netting agreement on the consolidated balance sheet as of December 31, 2020 . |
Fair Value of Financial Instr_5
Fair Value of Financial Instruments (Details-3) | 12 Months Ended | |
Dec. 31, 2021 | Dec. 31, 2020 | |
Basis adjustment: | ||
Basis adjustment - on peak | 94.10% | 94.20% |
Basis adjustment - off peak | 92.40% | 94.50% |
US Treasury Bills [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 | 41.00% | 46.00% |
Purchased power | 34.00% | 35.00% |
Maximum [Member] | ||
Counterparty fuel mix: | ||
Internal generation | 66.00% | 65.00% |
Purchased power | 59.00% | 54.00% |
Weighted Average [Member] | ||
Counterparty fuel mix: | ||
Internal generation | 56.60% | 56.50% |
Purchased power | 43.40% | 43.50% |
Fair Value of Financial Instr_6
Fair Value of Financial Instruments (Details-4) - USD ($) $ in Thousands | 12 Months Ended | |||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | ||
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward] | ||||
Beginning balance | $ (14,055) | $ (26,456) | $ (32,002) | |
Realized and unrealized gains (losses): | ||||
Included in regulatory assets | 0 | 12,402 | 5,545 | |
Included in regulatory liability | 14,234 | 0 | 0 | |
Included in other comprehensive income | 0 | 0 | 0 | |
Included in earnings | [1] | 5,521 | (6,439) | (3,765) |
Included in current assets | 237 | (87) | (70) | |
Purchases | 26,287 | 22,232 | 22,974 | |
Sales | 0 | 0 | 0 | |
Issuances | 0 | 0 | 0 | |
Settlements | (32,046) | (15,707) | (19,138) | |
Ending balance | $ 178 | $ (14,055) | $ (26,456) | |
[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. |
Fair Value of Financial Instr_7
Fair Value of Financial Instruments (Details-5) - USD ($) $ in Thousands | 12 Months Ended | |||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | ||
Fair Value Disclosures [Abstract] | ||||
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities | [1] | $ 0 | $ 0 | $ 0 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||
Included in earnings | [1] | 5,521 | (6,439) | (3,765) |
Purchased Power Expense [Member] | ||||
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||
Included in earnings | 6,192 | (5,888) | (3,334) | |
Cost Of Gas Sold Expense [Member] | ||||
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||
Included in earnings | $ (671) | $ (551) | $ (431) | |
[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. |
Revenue (Details-1)
Revenue (Details-1) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Total Operating Revenue [Member] | |||
Disaggregation of Revenue [Line Items] | |||
Revenues recognized from contracts with customers | $ 606,584 | $ 538,633 | $ 568,855 |
Electric [Member] | |||
Disaggregation of Revenue [Line Items] | |||
Revenues recognized from contracts with customers | 420,286 | 393,692 | 408,285 |
Electric [Member] | Residential [Member] | |||
Disaggregation of Revenue [Line Items] | |||
Revenues recognized from contracts with customers | 151,646 | 146,431 | 140,006 |
Electric [Member] | Commercial [Member] | |||
Disaggregation of Revenue [Line Items] | |||
Revenues recognized from contracts with customers | 210,475 | 198,043 | 213,265 |
Electric [Member] | Industrial [Member] | |||
Disaggregation of Revenue [Line Items] | |||
Revenues recognized from contracts with customers | 12,529 | 11,514 | 12,772 |
Electric [Member] | Other-retail/municipal [Member] | |||
Disaggregation of Revenue [Line Items] | |||
Revenues recognized from contracts with customers | 35,169 | 32,915 | 35,174 |
Electric [Member] | Total Retail [Member] | |||
Disaggregation of Revenue [Line Items] | |||
Revenues recognized from contracts with customers | 409,819 | 388,903 | 401,217 |
Electric [Member] | Sales To The Market [Member] | |||
Disaggregation of Revenue [Line Items] | |||
Revenues recognized from contracts with customers | 9,499 | 4,015 | 5,664 |
Electric [Member] | Other Revenues [Member] | |||
Disaggregation of Revenue [Line Items] | |||
Revenues recognized from contracts with customers | 968 | 774 | 1,404 |
Gas [Member] | |||
Disaggregation of Revenue [Line Items] | |||
Revenues recognized from contracts with customers | 185,620 | 144,261 | 159,875 |
Gas [Member] | Residential [Member] | |||
Disaggregation of Revenue [Line Items] | |||
Revenues recognized from contracts with customers | 110,442 | 88,765 | 95,146 |
Gas [Member] | Commercial/Industrial [Member] | |||
Disaggregation of Revenue [Line Items] | |||
Revenues recognized from contracts with customers | 68,895 | 49,682 | 59,051 |
Gas [Member] | Total Retail [Member] | |||
Disaggregation of Revenue [Line Items] | |||
Revenues recognized from contracts with customers | 179,337 | 138,447 | 154,197 |
Gas [Member] | Gas Transportation [Member] | |||
Disaggregation of Revenue [Line Items] | |||
Revenues recognized from contracts with customers | 6,185 | 5,713 | 5,293 |
Gas [Member] | Other Revenues [Member] | |||
Disaggregation of Revenue [Line Items] | |||
Revenues recognized from contracts with customers | 98 | 101 | 385 |
Non Regulated Energy [Member] | |||
Disaggregation of Revenue [Line Items] | |||
Revenues recognized from contracts with customers | $ 678 | $ 680 | $ 695 |
Noncontrolling Interest (Detail
Noncontrolling Interest (Details) - USD ($) $ in Thousands | 12 Months Ended | |||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | ||
MGE Power [Member] | ||||
Noncontrolling Interest [Line Items] | ||||
Ownership percentage by parent | 100.00% | |||
MGE [Member] | ||||
Noncontrolling Interest [Line Items] | ||||
Noncontrolling interest on balance sheet | $ 148,587 | $ 141,196 | ||
Net income attributable to noncontrolling interest, net of tax | $ 22,391 | 22,393 | $ 22,349 | |
MGE Power Elm Road [Member] | ||||
Noncontrolling Interest [Line Items] | ||||
Ownership percentage by parent | 100.00% | |||
Noncontrolling interest on balance sheet | [1] | $ 101,507 | 96,856 | |
Net income attributable to noncontrolling interest, net of tax | [1] | $ 15,151 | 15,184 | 15,153 |
MGE Power West Campus [Member] | ||||
Noncontrolling Interest [Line Items] | ||||
Ownership percentage by parent | 100.00% | |||
Noncontrolling interest on balance sheet | [1] | $ 47,080 | 44,340 | |
Net income attributable to noncontrolling interest, net of tax | [1] | $ 7,240 | $ 7,209 | $ 7,196 |
[1] | MGE Power Elm Road and MGE Power West Campus are not subsidiaries of MGE; however, they have been consolidated in the consolidated financial statements of MGE (see Footnote 3). MGE Power Elm Road and MGE Power West Campus are 100 % owned by MGE Power, and MGE Power is 100 % owned by MGE Energy. MGE Energy's proportionate share of the equity and net income (through its wholly owned subsidiary MGE Power) of MGE Power Elm Road and MGE Power West Campus is classified within the MGE consolidated financial statements as noncontrolling interest |
Segment Information (Details)
Segment Information (Details) - USD ($) $ in Thousands | 12 Months Ended | |||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | ||
Segment Reporting Information [Line Items] | ||||
Operating revenues | $ 606,584 | $ 538,633 | $ 568,855 | |
Depreciation and amortization | (76,983) | (74,188) | (71,562) | |
Operating Income (Loss) | 117,294 | 109,997 | 110,910 | |
Interest (expense) income, net | (24,112) | (23,521) | (23,063) | |
Income tax (provision) benefit | (4,115) | (19,423) | (19,784) | |
Equity earnings of investments | 9,270 | 10,221 | 9,889 | |
Net Income | 105,761 | 92,418 | 86,874 | |
Segment Reporting Information Assets And Capital Expenditures [Abstract] | ||||
Assets | 2,371,906 | 2,253,651 | 2,081,664 | |
Capital expenditures | 153,169 | 203,139 | 164,036 | |
Electric [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 420,286 | 393,692 | 408,285 | |
Gas [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 185,620 | 144,261 | 159,875 | |
Non Regulated Energy [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 678 | 680 | 695 | |
Transmission Investment [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 0 | 0 | 0 | |
All Others [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 0 | 0 | 0 | |
Operating Segments [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 606,584 | 538,633 | 568,855 | |
Depreciation and amortization | (76,983) | (74,188) | (71,562) | |
Operating Income (Loss) | 117,294 | 109,997 | 110,910 | |
Interest (expense) income, net | (24,112) | (23,521) | (23,063) | |
Income tax (provision) benefit | (4,115) | (19,423) | (19,784) | |
Equity earnings of investments | 9,270 | 10,221 | 9,547 | |
Operating Segments [Member] | Electric [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 420,842 | 394,457 | 409,091 | |
Depreciation and amortization | (56,672) | (54,658) | (52,755) | |
Operating Income (Loss) | 58,993 | 57,847 | 59,180 | |
Interest (expense) income, net | (15,261) | (14,446) | (14,978) | |
Income tax (provision) benefit | 10,672 | (4,230) | (5,037) | |
Equity earnings of investments | 0 | 0 | 0 | |
Net Income | 63,910 | 50,522 | 46,318 | |
Segment Reporting Information Assets And Capital Expenditures [Abstract] | ||||
Assets | 1,525,163 | 1,421,302 | 1,308,277 | |
Capital expenditures | 115,234 | 162,210 | 125,086 | |
Operating Segments [Member] | Gas [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 208,348 | 156,418 | 175,945 | |
Depreciation and amortization | (12,852) | (12,049) | (11,320) | |
Operating Income (Loss) | 25,133 | 19,674 | 19,528 | |
Interest (expense) income, net | (4,315) | (4,370) | (4,237) | |
Income tax (provision) benefit | (4,922) | (4,805) | (4,753) | |
Equity earnings of investments | 0 | 0 | 0 | |
Net Income | 15,511 | 14,167 | 14,088 | |
Segment Reporting Information Assets And Capital Expenditures [Abstract] | ||||
Assets | 485,345 | 444,702 | 408,001 | |
Capital expenditures | 34,071 | 36,906 | 36,193 | |
Operating Segments [Member] | Non Regulated Energy [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 41,544 | 41,082 | 40,715 | |
Depreciation and amortization | (7,459) | (7,481) | (7,487) | |
Operating Income (Loss) | 33,936 | 33,460 | 33,084 | |
Interest (expense) income, net | (4,577) | (4,826) | (5,083) | |
Income tax (provision) benefit | (7,998) | (7,800) | (7,628) | |
Equity earnings of investments | 0 | 0 | 0 | |
Net Income | 21,361 | 20,834 | 20,373 | |
Segment Reporting Information Assets And Capital Expenditures [Abstract] | ||||
Assets | 252,584 | 254,298 | 258,004 | |
Capital expenditures | 3,864 | 4,023 | 2,757 | |
Operating Segments [Member] | Transmission Investment [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 0 | 0 | 0 | |
Depreciation and amortization | 0 | |||
Operating Income (Loss) | 0 | (1) | 0 | |
Interest (expense) income, net | 0 | 0 | 0 | |
Income tax (provision) benefit | (2,486) | (2,786) | (2,602) | |
Equity earnings of investments | 9,339 | 10,221 | 9,547 | |
Net Income | 6,852 | 7,434 | 6,945 | |
Segment Reporting Information Assets And Capital Expenditures [Abstract] | ||||
Assets | [1] | 75,990 | 74,480 | 71,668 |
Capital expenditures | 0 | 0 | 0 | |
Operating Segments [Member] | All Others [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 0 | 0 | 0 | |
Depreciation and amortization | 0 | 0 | ||
Operating Income (Loss) | (768) | (983) | (882) | |
Interest (expense) income, net | 41 | 121 | 1,235 | |
Income tax (provision) benefit | 619 | 198 | 236 | |
Equity earnings of investments | (69) | 0 | 0 | |
Net Income | (1,873) | (539) | (850) | |
Segment Reporting Information Assets And Capital Expenditures [Abstract] | ||||
Assets | 467,954 | 495,483 | 443,278 | |
Capital expenditures | 0 | 0 | 0 | |
Consolidation Elimination Entries [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | (64,150) | (53,324) | (56,896) | |
Depreciation and amortization | 0 | |||
Operating Income (Loss) | 0 | 0 | 0 | |
Interest (expense) income, net | 0 | 0 | 0 | |
Income tax (provision) benefit | 0 | 0 | 0 | |
Equity earnings of investments | 0 | 0 | 0 | |
Net Income | 0 | 0 | 0 | |
Segment Reporting Information Assets And Capital Expenditures [Abstract] | ||||
Assets | (435,130) | (436,614) | (407,564) | |
Capital expenditures | 0 | 0 | 0 | |
Consolidation Elimination Entries [Member] | Electric [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 556 | 765 | 806 | |
Consolidation Elimination Entries [Member] | Gas [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 22,728 | 12,157 | 16,070 | |
Consolidation Elimination Entries [Member] | Non Regulated Energy [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 40,866 | 40,402 | 40,020 | |
Consolidation Elimination Entries [Member] | Transmission Investment [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 0 | 0 | 0 | |
Consolidation Elimination Entries [Member] | All Others [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 0 | 0 | 0 | |
MGE [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 606,584 | 538,633 | 568,855 | |
Depreciation and amortization | (76,983) | (74,188) | (71,562) | |
Operating Income (Loss) | 118,062 | 110,981 | 111,792 | |
Interest (expense) income, net | (24,153) | (23,642) | (24,298) | |
Income tax (provision) benefit | (2,248) | (16,835) | (17,418) | |
Net Income | 78,391 | 63,130 | 58,430 | |
Segment Reporting Information Assets And Capital Expenditures [Abstract] | ||||
Assets | 2,262,775 | 2,119,971 | 1,973,477 | |
Capital expenditures | 153,169 | 203,139 | 164,036 | |
MGE [Member] | Electric [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 420,286 | 393,692 | 408,285 | |
MGE [Member] | Gas [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 185,620 | 144,261 | 159,875 | |
MGE [Member] | Non Regulated Energy [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 678 | 680 | 695 | |
MGE [Member] | Operating Segments [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 606,584 | 538,633 | 568,855 | |
Depreciation and amortization | (76,983) | (74,188) | (71,562) | |
Operating Income (Loss) | 118,062 | 110,981 | 111,792 | |
Interest (expense) income, net | (24,153) | (23,642) | (24,298) | |
Income tax (provision) benefit | (2,248) | (16,835) | (17,418) | |
Net Income | 78,391 | 63,130 | 58,430 | |
MGE [Member] | Operating Segments [Member] | Electric [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 420,842 | 394,457 | 409,091 | |
Depreciation and amortization | (56,672) | (54,658) | (52,755) | |
Operating Income (Loss) | 58,993 | 57,847 | 59,180 | |
Interest (expense) income, net | (15,261) | (14,446) | (14,978) | |
Income tax (provision) benefit | 10,672 | (4,230) | (5,037) | |
Net Income | 63,910 | 50,522 | 46,318 | |
Segment Reporting Information Assets And Capital Expenditures [Abstract] | ||||
Assets | 1,525,163 | 1,421,302 | 1,308,277 | |
Capital expenditures | 115,234 | 162,210 | 125,086 | |
MGE [Member] | Operating Segments [Member] | Gas [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 208,348 | 156,418 | 175,945 | |
Depreciation and amortization | (12,852) | (12,049) | (11,320) | |
Operating Income (Loss) | 25,133 | 19,674 | 19,528 | |
Interest (expense) income, net | (4,315) | (4,370) | (4,237) | |
Income tax (provision) benefit | (4,922) | (4,805) | (4,753) | |
Net Income | 15,511 | 14,167 | 14,088 | |
Segment Reporting Information Assets And Capital Expenditures [Abstract] | ||||
Assets | 485,345 | 444,702 | 408,001 | |
Capital expenditures | 34,071 | 36,906 | 36,193 | |
MGE [Member] | Operating Segments [Member] | Non Regulated Energy [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 41,544 | 41,082 | 40,715 | |
Depreciation and amortization | (7,459) | (7,481) | (7,487) | |
Operating Income (Loss) | 33,936 | 33,460 | 33,084 | |
Interest (expense) income, net | (4,577) | (4,826) | (5,083) | |
Income tax (provision) benefit | (7,998) | (7,800) | (7,628) | |
Net Income | 21,361 | 20,834 | 20,373 | |
Segment Reporting Information Assets And Capital Expenditures [Abstract] | ||||
Assets | 252,534 | 254,248 | 257,954 | |
Capital expenditures | 3,864 | 4,023 | 2,757 | |
MGE [Member] | Consolidation Elimination Entries [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | (64,150) | (53,324) | (56,896) | |
Depreciation and amortization | 0 | 0 | 0 | |
Operating Income (Loss) | 0 | 0 | 0 | |
Interest (expense) income, net | 0 | 0 | 0 | |
Income tax (provision) benefit | 0 | 0 | 0 | |
Net Income | (22,391) | (22,393) | (22,349) | |
Segment Reporting Information Assets And Capital Expenditures [Abstract] | ||||
Assets | (267) | (281) | (755) | |
Capital expenditures | 0 | 0 | 0 | |
MGE [Member] | Consolidation Elimination Entries [Member] | Electric [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 556 | 765 | 806 | |
MGE [Member] | Consolidation Elimination Entries [Member] | Gas [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 22,728 | 12,157 | 16,070 | |
MGE [Member] | Consolidation Elimination Entries [Member] | Non Regulated Energy [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | $ 40,866 | $ 40,402 | $ 40,020 | |
[1] | The Transmission Investment segment represents MGE Energy's investment in equity method investees. |
Schedule I - Condensed Parent C
Schedule I - Condensed Parent Company Finanical Statements (Details-Comprehensive Income Statement) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Operating Expenses: | |||
Other operations and maintenance | $ 199,316 | $ 186,430 | $ 193,322 |
Total Operating Expenses | 489,290 | 428,636 | 457,945 |
Operating Income | 117,294 | 109,997 | 110,910 |
Equity earnings of investments | 9,270 | 10,221 | 9,889 |
Income before income taxes | 109,876 | 111,841 | 106,658 |
Income tax provision | (4,115) | (19,423) | (19,784) |
Net Income | 105,761 | 92,418 | 86,874 |
MGE Energy [Member] | |||
Operating Expenses: | |||
Other operations and maintenance | 711 | 882 | 815 |
Total Operating Expenses | 711 | 882 | 815 |
Operating Income | (711) | (882) | (815) |
Equity earnings of investments | 107,883 | 92,922 | 87,728 |
Other income/(loss), net | (2,163) | 94 | (1,500) |
Interest income, net | 5 | 78 | 1,224 |
Income before income taxes | 105,014 | 92,212 | 86,637 |
Income tax provision | 747 | 206 | 237 |
Net Income | $ 105,761 | $ 92,418 | $ 86,874 |
Schedule I - Condensed Parent_2
Schedule I - Condensed Parent Company Finanical Statements (Details-Cash Flow Statement) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Condensed Cash Flow Statements, Captions [Line Items] | |||
Cash provided by operating activities | $ 137,527 | $ 172,443 | $ 130,475 |
Investing Activities: | |||
Other | 221 | (1,672) | (508) |
Cash Used for Investing Activities | (156,975) | (210,412) | (172,357) |
Financing Activities: | |||
Proceeds From Issuance Of Common Stock | 0 | 79,635 | 0 |
Cash dividends paid on common stock | (54,788) | (51,729) | (47,842) |
Other | (2,197) | (1,553) | (1,838) |
Cash Provided by (Used for) Financing Activities | (8,756) | 59,194 | (17,233) |
Change in cash, cash equivalents, and restricted cash: | (28,204) | 21,225 | (59,115) |
Cash, cash equivalents, and restricted cash at beginning of period | 47,039 | 25,814 | 84,929 |
Cash, cash equivalents, and restricted cash at end of period | 18,835 | 47,039 | 25,814 |
MGE Energy [Member] | |||
Condensed Cash Flow Statements, Captions [Line Items] | |||
Cash provided by operating activities | 27,535 | 27,631 | 27,901 |
Investing Activities: | |||
Contributions to affiliates | 0 | (32,157) | (33,631) |
Contributions to other Investments | (4,006) | (3,809) | (4,496) |
Other | 843 | 622 | 214 |
Cash Used for Investing Activities | (3,163) | (35,344) | (37,913) |
Financing Activities: | |||
Proceeds From Issuance Of Common Stock | 0 | 79,635 | 0 |
Cash dividends paid on common stock | (54,788) | (51,729) | (47,842) |
Cash Provided by (Used for) Financing Activities | (54,788) | (27,906) | (47,842) |
Change in cash, cash equivalents, and restricted cash: | (30,416) | (20,193) | (57,854) |
Cash, cash equivalents, and restricted cash at beginning of period | 37,375 | 17,182 | 75,036 |
Cash, cash equivalents, and restricted cash at end of period | $ 6,959 | $ 37,375 | $ 17,182 |
Schedule I - Condensed Parent_3
Schedule I - Condensed Parent Company Finanical Statements (Details-Balance Sheet) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | Dec. 31, 2018 |
Current Assets: | ||||
Cash and cash equivalents | $ 17,438 | $ 44,738 | ||
Other current assets | 11,183 | 11,394 | ||
Total Current Assets | 199,371 | 209,519 | ||
Other deferred assets and other | ||||
Other deferred assets and other | 27,548 | 22,259 | ||
Investments: | ||||
Other investments | 2,324 | 2,308 | ||
Total investments | 98,754 | 94,676 | ||
Total Assets | 2,371,906 | 2,253,651 | $ 2,081,664 | |
Current Liabilities: | ||||
Other current liabilities | 8,468 | 6,015 | ||
Total Current Liabilities | 117,847 | 190,926 | ||
Other Credits: | ||||
Deferred income taxes | 231,149 | 231,471 | ||
Other deferred liabilities and other | 91,690 | 72,211 | ||
Total Other Credits | 612,380 | 567,422 | ||
Shareholders' Equity: | ||||
Retained earnings | 596,402 | 545,429 | ||
Total Common Shareholders' Equity | 1,027,468 | 976,000 | $ 855,676 | $ 816,644 |
Commitments and contingencies (see Footnote 3) | ||||
Total Liabilities and Capitalization | 2,371,906 | 2,253,651 | ||
MGE Energy [Member] | ||||
Current Assets: | ||||
Cash and cash equivalents | 6,959 | 37,375 | ||
Other current assets | 1,681 | 1,494 | ||
Total Current Assets | 8,640 | 38,869 | ||
Other deferred assets and other | ||||
Other deferred assets and other | 244 | 364 | ||
Investments: | ||||
Investments in affiliates | 1,036,347 | 953,810 | ||
Other investments | 18,927 | 15,634 | ||
Total investments | 1,055,274 | 969,444 | ||
Total Assets | 1,064,158 | 1,008,677 | ||
Current Liabilities: | ||||
Accounts payable to affiliates | 548 | 530 | ||
Other current liabilities | 2,516 | 66 | ||
Total Current Liabilities | 3,064 | 596 | ||
Other Credits: | ||||
Deferred income taxes | 32,014 | 29,926 | ||
Accounts payable to affiliates | 1,589 | 2,118 | ||
Other deferred liabilities and other | 23 | 37 | ||
Total Other Credits | 33,626 | 32,081 | ||
Shareholders' Equity: | ||||
Common shareholders' equity | 431,066 | 430,571 | ||
Retained earnings | 596,402 | 545,429 | ||
Total Common Shareholders' Equity | 1,027,468 | 976,000 | ||
Commitments and contingencies (see Footnote 3) | ||||
Total Liabilities and Capitalization | $ 1,064,158 | $ 1,008,677 |
Schedule I - Condensed Parent_4
Schedule I - Condensed Parent Company Finanical Statements (Details-Notes 1) - Line of Credit [Member] - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 | |
Credit facilities [Line Items] | |||
Line Of Credit Facility Current Borrowing Capacity | [1] | $ 143,815 | $ 96,815 |
MGE Energy unsecured committed revolving line of credit totaling $50 million [Member] | MGE Energy [Member] | |||
Credit facilities [Line Items] | |||
Line of credit, borrowings outstanding | $ 0 | ||
[1] | MGE Energy short-term borrowings include MGE Energy and MGE lines of credit and MGE commercial paper. |
Schedule I - Condensed Parent_5
Schedule I - Condensed Parent Company Finanical Statements (Details-Notes 2) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021USD ($) | Dec. 31, 2020USD ($) | Dec. 31, 2019USD ($) | |
MGE Energy [Member] | |||
Dividends from Affiliates [Line Items] | |||
Cash dividends paid to parent by MGE | $ 25,464 | $ 27,714 | $ 28,246 |
First Mortgage Bonds [Member] | 7.70%, 2028 Series [Member] | |||
Dividend Restrictions | |||
Debt covenant, allowable amount available for payment of dividends | 604,300 | ||
MGE [Member] | |||
Dividends from Affiliates [Line Items] | |||
Cash dividends paid to parent by MGE | $ 5,000 | 0 | 0 |
Dividend Restrictions | |||
Common equity ratio | 0.607 | ||
MGE [Member] | Minimum [Member] | |||
Dividend Restrictions | |||
Dividend restrictions, common equity ratio | 0.55 | ||
MGE Power Elm Road [Member] | |||
Dividends from Affiliates [Line Items] | |||
Cash dividends paid to parent by MGE | $ 10,500 | 15,500 | 15,500 |
MGE Power West Campus [Member] | |||
Dividends from Affiliates [Line Items] | |||
Cash dividends paid to parent by MGE | 4,500 | 6,000 | 8,000 |
MGE Transco [Member] | |||
Dividends from Affiliates [Line Items] | |||
Cash dividends paid to parent by MGE | 5,464 | 5,864 | 4,653 |
MGEE Transco [Member] | |||
Dividends from Affiliates [Line Items] | |||
Cash dividends paid to parent by MGE | $ 0 | $ 350 | $ 93 |
Schedule II - Valuation and Qua
Schedule II - Valuation and Qualifying Accounts (Details) - USD ($) | 12 Months Ended | |||||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | ||||
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||
Balance at beginning of period | $ 7,076,565 | $ 3,258,269 | $ 3,153,662 | |||
Charged to costs and expenses | 3,402,468 | [1] | 5,164,943 | [1] | 1,614,943 | |
Charged to other accounts | 32,400 | 26,400 | 20,160 | |||
Net accounts written off | [2] | (2,207,732) | (1,373,047) | (1,530,496) | ||
Balance at end of period | 8,303,701 | 7,076,565 | $ 3,258,269 | |||
Deferred Bad Debt Expense [Member] | ||||||
Regulatory Assets [Line Items] | ||||||
Regulatory assets | $ 1,800,000 | $ 3,800,000 | ||||
[1] | During the year ended December 31, 2021 and 2020 , MGE deferred $ 1.8 million and $ 3.8 million, respectively, of bad debt expense as a regulatory asset. See Footnote 8 of the Notes to Consolidated Financial Statements in this Report for further information. | |||||
[2] | Net of recovery of amounts previously written off |