COVER PAGE
COVER PAGE | 9 Months Ended |
Sep. 30, 2023 shares | |
Cover [Abstract] | |
Document type | 10-Q |
Document Quarterly Report | true |
Document period end date | Sep. 30, 2023 |
Document Transition Report | false |
Entity File Number | 001-03016 |
Entity registrant name | WISCONSIN PUBLIC SERVICE CORPORATION |
Entity Tax Identification Number | 39-0715160 |
Entity Incorporation, State or Country Code | WI |
Entity Address, Address Line One | 2830 South Ashland Avenue |
Entity Address, Address Line Two | P.O. Box 19001 |
Entity Address, City or Town | Green Bay |
Entity Address, State or Province | WI |
Entity Address, Postal Zip Code | 54307-9001 |
City Area Code | 800 |
Local Phone Number | 450-7260 |
Entity Current Reporting Status | Yes |
Entity Interactive Data Current | Yes |
Entity filer category | Non-accelerated Filer |
Small business | false |
Emerging growth company | false |
Entity Shell Company | false |
Entity common stock, shares outstanding | 23,896,962 |
Entity central index key | 0000107833 |
Amendment flag | false |
Current fiscal year end date | --12-31 |
Document fiscal year focus | 2023 |
Document fiscal period focus | Q3 |
CONDENSED INCOME STATEMENTS
CONDENSED INCOME STATEMENTS - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Income Statement [Abstract] | ||||
Operating revenues | $ 411.6 | $ 435.3 | $ 1,284.1 | $ 1,332.7 |
Operating expenses | ||||
Cost of sales | 116.4 | 198.5 | 461.6 | 610.7 |
Other operation and maintenance | 107.2 | 89.9 | 320.5 | 268 |
Depreciation and amortization | 57.5 | 50.1 | 168.7 | 149.3 |
Property and revenue taxes | 11.8 | 10.4 | 35.7 | 32 |
Total operating expenses | 292.9 | 348.9 | 986.5 | 1,060 |
Operating income | 118.7 | 86.4 | 297.6 | 272.7 |
Other income, net | 11.2 | 11 | 35.6 | 32.7 |
Interest expense | 22.3 | 17.3 | 66.3 | 50.5 |
Other expense | (11.1) | (6.3) | (30.7) | (17.8) |
Income before income taxes | 107.6 | 80.1 | 266.9 | 254.9 |
Income tax expense | 21.4 | 18.9 | 50.3 | 60.5 |
Net income | $ 86.2 | $ 61.2 | $ 216.6 | $ 194.4 |
CONDENSED BALANCE SHEETS
CONDENSED BALANCE SHEETS - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Current assets | ||
Cash and cash equivalents | $ 1.5 | $ 0.5 |
Accounts receivable and unbilled revenues, net of reserves of $9.6 and $11.7, respectively | 202.7 | 267.8 |
Accounts receivable from related parties | 25.6 | 31.8 |
Materials, supplies, and inventories | 156.3 | 164.5 |
Prepaid taxes | 35.1 | 58.4 |
Other prepayments | 3.5 | 6 |
Collateral on deposit | 21.8 | 26.6 |
Other | 5.4 | 9.5 |
Current assets | 451.9 | 565.1 |
Long-term assets | ||
Property, plant, and equipment, net of accumulated depreciation and amortization of $1,997.0 and $1,820.6, respectively | 5,740.1 | 5,376.7 |
Regulatory assets | 348.1 | 365.5 |
Goodwill | 36.4 | 36.4 |
Pension and OPEB assets | 300.7 | 282.1 |
Other | 44.1 | 83 |
Long-term assets | 6,469.4 | 6,143.7 |
Total assets | 6,921.3 | 6,708.8 |
Current liabilities | ||
Short-term debt | 131 | 194.9 |
Accounts payable | 108.3 | 176.9 |
Accounts payable to related parties | 57.8 | 49.8 |
Accrued payroll and benefits | 23.6 | 22.4 |
Accrued interest | 27.3 | 12 |
Amounts refundable to customers | 17.6 | 9.9 |
Customer credit balances | 22.9 | 20.1 |
Other | 22.2 | 33.8 |
Current liabilities | 410.7 | 519.8 |
Long-term liabilities | ||
Long-term debt | 2,007.8 | 1,999.9 |
Deferred income taxes | 904.1 | 860.7 |
Deferred ITCs | 75.2 | 78.5 |
Regulatory liabilities | 669.9 | 650.3 |
Environmental remediation liabilities | 78.5 | 88.6 |
Other | 135 | 127.7 |
Long-term liabilities | 3,870.5 | 3,805.7 |
Commitments and contingencies (Note 19) | ||
Common shareholder's equity | ||
Common stock – $4 par value; 32,000,000 shares authorized; 23,896,962 shares issued and outstanding | 95.6 | 95.6 |
Additional paid in capital | 1,782 | 1,616.8 |
Retained earnings | 762.5 | 670.9 |
Common shareholders' equity | 2,640.1 | 2,383.3 |
Total liabilities and equity | $ 6,921.3 | $ 6,708.8 |
CONDENSED BALANCE SHEETS (PAREN
CONDENSED BALANCE SHEETS (PARENTHETICAL) - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Statement of Financial Position [Abstract] | ||
Accounts receivable and unbilled revenues, reserves | $ 9.6 | $ 11.7 |
Property, plant, and equipment, accumulated depreciation and amortization | $ 1,997 | $ 1,820.6 |
Common stock, par value (in dollars per share) | $ 4 | $ 4 |
Common stock, shares authorized | 32,000,000 | 32,000,000 |
Common stock, shares issued | 23,896,962 | 23,896,962 |
Common stock, shares outstanding | 23,896,962 | 23,896,962 |
CONDENSED STATEMENTS OF CASH FL
CONDENSED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2023 | Sep. 30, 2022 | |
Operating activities | ||
Net income | $ 216.6 | $ 194.4 |
Reconciliation to cash provided by operating activities | ||
Depreciation and amortization | 168.7 | 149.3 |
Deferred income taxes and ITCs, net | 27.4 | 42.5 |
Change in – | ||
Accounts receivable and unbilled revenues, net | 74.5 | 3.6 |
Materials, supplies, and inventories | 13.1 | (56) |
Prepaid taxes | 23.3 | 10 |
Collateral on deposit | 4.8 | (0.2) |
Other current assets | 5.3 | 3.1 |
Accounts payable | (61.9) | 28 |
Accrued interest | 15.3 | 10.9 |
Amounts refundable to customers | 7.7 | (3.3) |
Other current liabilities | (1.9) | (2.9) |
Other, net | 8.1 | (67.7) |
Net cash provided by operating activities | 501 | 311.7 |
Investing activities | ||
Capital expenditures | (333.1) | (306.3) |
Acquisition of Whitewater | (38) | 0 |
Acquisition of Red Barn | (143.8) | 0 |
Reimbursement for ATC's construction costs | 0 | 10 |
Proceeds from cash surrender value of life insurance | 0 | 4.4 |
Other, net | 1 | 2.8 |
Net cash used in investing activities | (513.9) | (289.1) |
Financing activities | ||
Change in short-term debt | (63.9) | (59.6) |
Payment of dividends to parent | (125) | (90) |
Equity contribution from parent | 165 | 125 |
Other, net | (0.2) | (0.4) |
Net cash used in financing activities | (24.1) | (25) |
Net change in cash, cash equivalents, and restricted cash | (37) | (2.4) |
Cash, cash equivalents, and restricted cash at beginning of period | 38.5 | 2.4 |
Cash, cash equivalents, and restricted cash at end of period | $ 1.5 | $ 0 |
CONDENSED STATEMENTS OF EQUITY
CONDENSED STATEMENTS OF EQUITY - USD ($) $ in Millions | Total | Total common shareholder's equity | Common stock | Additional paid in capital | Retained earnings |
Balance at Dec. 31, 2021 | $ 2,143 | $ 95.6 | $ 1,491.5 | $ 555.9 | |
Statements of equity | |||||
Net income | 76.6 | 0 | 0 | 76.6 | |
Equity contribution from parent | 125 | 0 | 125 | 0 | |
Payment of dividends to parent | (30) | 0 | 0 | (30) | |
Stock-based compensation and other | 0.2 | 0 | 0.2 | 0 | |
Balance at Mar. 31, 2022 | 2,314.8 | 95.6 | 1,616.7 | 602.5 | |
Balance at Dec. 31, 2021 | 2,143 | 95.6 | 1,491.5 | 555.9 | |
Statements of equity | |||||
Net income | $ 194.4 | ||||
Equity contribution from parent | 125 | ||||
Payment of dividends to parent | (90) | ||||
Balance at Sep. 30, 2022 | 2,372.6 | 95.6 | 1,616.7 | 660.3 | |
Balance at Mar. 31, 2022 | 2,314.8 | 95.6 | 1,616.7 | 602.5 | |
Statements of equity | |||||
Net income | 56.6 | 0 | 0 | 56.6 | |
Payment of dividends to parent | (30) | 0 | 0 | (30) | |
Balance at Jun. 30, 2022 | 2,341.4 | 95.6 | 1,616.7 | 629.1 | |
Statements of equity | |||||
Net income | 61.2 | 61.2 | 0 | 0 | 61.2 |
Payment of dividends to parent | (30) | 0 | 0 | (30) | |
Balance at Sep. 30, 2022 | 2,372.6 | 95.6 | 1,616.7 | 660.3 | |
Balance at Dec. 31, 2022 | 2,383.3 | 95.6 | 1,616.8 | 670.9 | |
Statements of equity | |||||
Net income | 66.3 | 0 | 0 | 66.3 | |
Equity contribution from parent | 165 | 0 | 165 | 0 | |
Payment of dividends to parent | (65) | 0 | 0 | (65) | |
Stock-based compensation and other | 0.1 | 0 | 0.1 | 0 | |
Balance at Mar. 31, 2023 | 2,549.7 | 95.6 | 1,781.9 | 672.2 | |
Balance at Dec. 31, 2022 | 2,383.3 | 95.6 | 1,616.8 | 670.9 | |
Statements of equity | |||||
Net income | 216.6 | ||||
Equity contribution from parent | 165 | ||||
Payment of dividends to parent | (125) | ||||
Balance at Sep. 30, 2023 | 2,640.1 | 95.6 | 1,782 | 762.5 | |
Balance at Mar. 31, 2023 | 2,549.7 | 95.6 | 1,781.9 | 672.2 | |
Statements of equity | |||||
Net income | 64.1 | 0 | 0 | 64.1 | |
Payment of dividends to parent | (30) | 0 | 0 | (30) | |
Stock-based compensation and other | 0.1 | 0 | 0.1 | 0 | |
Balance at Jun. 30, 2023 | 2,583.9 | 95.6 | 1,782 | 706.3 | |
Statements of equity | |||||
Net income | $ 86.2 | 86.2 | 0 | 0 | 86.2 |
Payment of dividends to parent | (30) | 0 | 0 | (30) | |
Balance at Sep. 30, 2023 | $ 2,640.1 | $ 95.6 | $ 1,782 | $ 762.5 |
GENERAL INFORMATION
GENERAL INFORMATION | 9 Months Ended |
Sep. 30, 2023 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
GENERAL INFORMATION | GENERAL INFORMATION Wisconsin Public Service Corporation serves approximately 464,000 electric customers and 342,000 natural gas customers. As used in these notes, the term "financial statements" refers to the condensed financial statements. This includes the income statements, balance sheets, statements of cash flows, and statements of equity, unless otherwise noted. In this report, when we refer to "the Company," "us," "we," "our," or "ours," we are referring to Wisconsin Public Service Corporation. Investments in companies not controlled by us, but over which we have significant influence regarding the operating and financial policies of the investee, are accounted for using the equity method. We have prepared the unaudited interim financial statements presented in this Form 10-Q pursuant to the rules and regulations of the SEC and GAAP. Accordingly, these financial statements do not include all of the information and footnotes required by GAAP for annual financial statements. These financial statements should be read in conjunction with the financial statements and footnotes in our Annual Report on Form 10-K for the year ended December 31, 2022. Financial results for an interim period may not give a true indication of results for the year. In particular, the results of operations for the three and nine months ended September 30, 2023, are not necessarily indicative of expected results for 2023 due to seasonal variations and other factors. In management's opinion, we have included all adjustments, normal and recurring in nature, necessary for a fair presentation of our financial results. |
ACQUISITIONS
ACQUISITIONS | 9 Months Ended |
Sep. 30, 2023 | |
Asset Acquisition [Abstract] | |
ACQUISITIONS | ACQUISITIONS In accordance with Topic 805: Clarifying the Definition of a Business (ASU 2017-01), transactions are evaluated and are accounted for as acquisitions of assets or businesses, and transaction costs are capitalized in asset acquisitions. It was determined that all of the below acquisitions met the criteria of asset acquisitions. Acquisitions of Electric Generation Facilities in Wisconsin In April 2023, we, along with an unaffiliated utility, completed the acquisition of Red Barn, a commercially operational utility-scale wind-powered electric generating facility. The project is located in Grant County, Wisconsin and we own 82 MWs of this project. Our share of the cost of this project was $143.8 million. Red Barn qualifies for PTCs. In January 2023, we, along with WE, completed the acquisition of Whitewater, a commercially operational 236.5 MW dual fueled (natural gas and low sulfur fuel oil) combined cycle electric generation facility in Whitewater, Wisconsin. Our share of the cost of this facility was $38.0 million for 50% of the capacity. |
OPERATING REVENUES
OPERATING REVENUES | 9 Months Ended |
Sep. 30, 2023 | |
Revenue from Contract with Customer [Abstract] | |
OPERATING REVENUES | OPERATING REVENUES For more information about our operating revenues, see Note 1(d), Operating Revenues, in our 2022 Annual Report on Form 10-K. Disaggregation of Operating Revenues The following tables present our operating revenues disaggregated by revenue source for our utility segment. We do not have any revenues associated with our other segment. We disaggregate revenues into categories that depict how the nature, amount, timing, and uncertainty of revenues and cash flows are affected by economic factors. Revenues are further disaggregated by electric and natural gas operations and then by customer class. Each customer class within our electric and natural gas operations has different expectations of service, energy and demand requirements, and can be impacted differently by regulatory activities within their jurisdictions. Three Months Ended September 30 Nine Months Ended September 30 (in millions) 2023 2022 2023 2022 Wisconsin Public Service Corporation Electric utility $ 370.1 $ 373.0 $ 1,009.9 $ 1,016.3 Natural gas utility 40.9 61.7 272.3 312.9 Total revenues from contracts with customers 411.0 434.7 1,282.2 1,329.2 Other operating revenues 0.6 0.6 1.9 3.5 Total operating revenues $ 411.6 $ 435.3 $ 1,284.1 $ 1,332.7 Revenues from Contracts with Customers Electric Utility Operating Revenues The following table disaggregates electric utility operating revenues by customer class: Three Months Ended September 30 Nine Months Ended September 30 (in millions) 2023 2022 2023 2022 Residential $ 131.1 $ 122.6 $ 365.5 $ 351.0 Small commercial and industrial 130.2 116.8 343.9 318.4 Large commercial and industrial 79.1 87.8 211.9 230.5 Other 2.1 2.2 6.5 6.6 Total retail revenues 342.5 329.4 927.8 906.5 Wholesale 21.2 28.1 63.8 73.6 Resale 4.4 9.1 14.7 21.2 Other utility revenues 2.0 6.4 3.6 15.0 Total electric utility operating revenues $ 370.1 $ 373.0 $ 1,009.9 $ 1,016.3 Natural Gas Utility Operating Revenues The following table disaggregates natural gas utility operating revenues by customer class: Three Months Ended September 30 Nine Months Ended September 30 (in millions) 2023 2022 2023 2022 Residential $ 21.2 $ 29.6 $ 167.9 $ 178.6 Commercial and industrial 10.8 22.6 95.6 116.4 Total retail revenues 32.0 52.2 263.5 295.0 Transportation 4.4 3.9 16.2 14.6 Other utility revenues (1) 4.5 5.6 (7.4) 3.3 Total natural gas utility operating revenues $ 40.9 $ 61.7 $ 272.3 $ 312.9 (1) Includes the revenues subject to our purchased gas recovery mechanism, which fluctuate based on actual natural gas costs incurred, compared with the recovery of natural gas costs that were anticipated in rates. Other Operating Revenues Other operating revenues consist primarily of the following: Three Months Ended September 30 Nine Months Ended September 30 (in millions) 2023 2022 2023 2022 Late payment charges $ 0.8 $ 0.8 $ 3.1 $ 3.0 Alternative revenues (1) (0.3) (0.3) (1.5) 0.2 Other 0.1 0.1 0.3 0.3 Total other operating revenues $ 0.6 $ 0.6 $ 1.9 $ 3.5 (1) Negative amounts can result from alternative revenues being reversed to revenues from contracts with customers as the customer is billed for these alternative revenues. Negative amounts can also result from revenues to be refunded to wholesale customers subject to true-ups, as discussed in Note 1(d), Operating Revenues, in our 2022 Annual Report on Form 10-K. |
CREDIT LOSSES
CREDIT LOSSES | 9 Months Ended |
Sep. 30, 2023 | |
Credit Loss [Abstract] | |
CREDIT LOSSES | CREDIT LOSSES Our exposure to credit losses is related to our accounts receivable and unbilled revenue balances, which are generated from the sale of electricity and natural gas by our regulated utility operations. Our regulated utility operations are included in our utility segment. No accounts receivable and unbilled revenue balances were reported in the other segment at September 30, 2023 and December 31, 2022. We evaluate the collectability of our accounts receivable and unbilled revenue balances considering a combination of factors. For some of our larger customers and also in circumstances where we become aware of a specific customer's inability to meet its financial obligations to us, we record a specific allowance for credit losses against amounts due in order to reduce the net recognized receivable to the amount we reasonably believe will be collected. For all other customers, we use the accounts receivable aging method to calculate an allowance for credit losses. Using this method, we classify accounts receivable into different aging buckets and calculate a reserve percentage for each aging bucket based upon historical loss rates. The calculated reserve percentages are updated on at least an annual basis, in order to ensure recent macroeconomic, political, and regulatory trends are captured in the calculation, to the extent possible. Risks identified that we do not believe are reflected in the calculated reserve percentages, are assessed on a quarterly basis to determine whether further adjustments are required. We monitor our ongoing credit exposure through active review of counterparty accounts receivable balances against contract terms and due dates. Our activities include timely account reconciliation, dispute resolution and payment confirmation. To the extent possible, we work with customers with past due balances to negotiate payment plans, but will disconnect customers for non-payment as allowed by the PSCW, if necessary, and employ collection agencies and legal counsel to pursue recovery of defaulted receivables. For our larger customers, detailed credit review procedures may be performed in advance of any sales being made. We sometimes require letters of credit, parental guarantees, prepayments or other forms of credit assurance from our larger customers to mitigate credit risk. We have included a table below that shows our gross third-party receivable balances and related allowance for credit losses. (in millions) September 30, 2023 December 31, 2022 Accounts receivable and unbilled revenues $ 212.3 $ 279.5 Allowance for credit losses 9.6 11.7 Accounts receivable and unbilled revenues, net (1) $ 202.7 $ 267.8 Total accounts receivable, net – past due greater than 90 days (1) $ 7.5 $ 8.4 Past due greater than 90 days – collection risk mitigated by regulatory mechanisms (1) 93.7 % 95.5 % (1) Our exposure to credit losses for certain regulated utility customers is mitigated by a regulatory mechanism we have in place. Specifically, our residential tariffs include a mechanism for cost recovery or refund of uncollectible expense based on the difference between actual uncollectible write-offs and the amounts recovered in rates. As a result, at September 30, 2023, $79.1 million, or 39.0%, of our net accounts receivable and unbilled revenues balance had regulatory protections in place to mitigate the exposure to credit losses. A rollforward of the allowance for credit losses is included below: Three Months Ended September 30 (in millions) 2023 2022 Balance at July 1 $ 10.6 $ 10.8 Provision for credit losses 1.9 1.6 Provision for credit losses deferred for future recovery or refund (0.3) (1.2) Write-offs charged against the allowance (3.3) (3.0) Recoveries of amounts previously written off 0.7 1.4 Balance at September 30 $ 9.6 $ 9.6 Nine Months Ended September 30 (in millions) 2023 2022 Balance at January 1 $ 11.7 $ 11.1 Provision for credit losses 3.4 5.6 Provision for credit losses deferred for future recovery or refund 0.2 (1.8) Write-offs charged against the allowance (9.7) (9.3) Recoveries of amounts previously written off 4.0 4.0 Balance at September 30 $ 9.6 $ 9.6 There was a $2.1 million decrease in the allowance for credit losses at September 30, 2023, compared to January 1, 2023. The decrease was driven by customer write-offs related to the end of the winter moratorium. After a customer is disconnected for a period of time without payment on their account, we will write off that customer balance. In addition, lower energy costs driven by lower natural gas prices contributed to a reduction in past due accounts receivable balances and a related decrease in the allowance for credit losses. There was a $1.5 million decrease in the allowance for credit losses at September 30, 2022, compared to January 1, 2022. The decrease was driven by customer write-offs related to collection practices returning to pre-pandemic levels in 2021, including the restoration of our ability to disconnect customers. Partially offsetting the decrease in the allowance for credit losses, we believe that the high energy costs that customers experienced during this time, which were driven by high natural gas prices, contributed to higher past due accounts receivable balances and a related increase in the allowance for credit losses. |
REGULATORY ASSETS AND LIABILITI
REGULATORY ASSETS AND LIABILITIES | 9 Months Ended |
Sep. 30, 2023 | |
Regulatory Assets and Liabilities Disclosure [Abstract] | |
REGULATORY ASSETS AND LIABILITIES | REGULATORY ASSETS AND LIABILITIES The following regulatory assets and liabilities were reflected on our balance sheets at September 30, 2023 and December 31, 2022. For more information on our regulatory assets and liabilities, see Note 6, Regulatory Assets and Liabilities, in our 2022 Annual Report on Form 10-K. (in millions) September 30, 2023 December 31, 2022 Regulatory assets Environmental remediation costs $ 114.9 $ 118.5 Income tax related items 58.0 61.5 Pension and OPEB costs 47.9 48.6 Plant retirement related items 39.7 43.1 Asset retirement obligations 18.3 15.6 Derivatives 14.2 22.5 Bluewater (1) 11.1 6.8 ReACT™ 11.0 13.0 Energy efficiency programs 7.1 13.4 Uncollectible expense 6.6 5.6 Other, net 19.3 16.9 Total regulatory assets $ 348.1 $ 365.5 (1) Primarily related to costs associated with our long-term service agreement with Bluewater for natural gas storage services. The PSCW has approved escrow accounting for these costs. As a result, we defer as a regulatory asset or liability the difference between actual storage costs and those included in rates until recovery or refund is authorized in a future rate proceeding. (in millions) September 30, 2023 December 31, 2022 Regulatory liabilities Income tax related items $ 334.4 $ 343.7 Removal costs 189.2 186.5 Pension and OPEB benefits 92.5 90.1 Energy costs refundable through rate adjustments 37.0 9.9 Derivatives 5.2 7.9 Other, net 29.2 22.1 Total regulatory liabilities $ 687.5 $ 660.2 Balance sheet presentation Amounts refundable to customers $ 17.6 $ 9.9 Regulatory liabilities 669.9 650.3 Total regulatory liabilities $ 687.5 $ 660.2 |
PROPERTY, PLANT, AND EQUIPMENT
PROPERTY, PLANT, AND EQUIPMENT | 9 Months Ended |
Sep. 30, 2023 | |
Property, Plant and Equipment [Abstract] | |
PROPERTY, PLANT, AND EQUIPMENT | PROPERTY, PLANT, AND EQUIPMENT Plant to be Retired Columbia Units 1 and 2 As a result of a MISO ruling received in June 2021, retirement of the jointly-owned Columbia Units 1 and 2 became probable. Columbia Units 1 and 2 are expected to be retired by June 2026. The total net book value of our ownership share of Columbia Units 1 and 2 was $261.8 million at September 30, 2023, which does not include deferred taxes. This amount was classified as plant to be retired within property, plant, and equipment on our balance sheet. These units are included in rate base, and we continue to depreciate them on a straight-line basis using the composite depreciation rates approved by the PSCW. |
JOINTLY OWNED UTILITY FACILITIE
JOINTLY OWNED UTILITY FACILITIES | 9 Months Ended |
Sep. 30, 2023 | |
Jointly Owned Utility Plant, Net Ownership Amount [Abstract] | |
JOINTLY OWNED UTILITY FACILITIES | JOINTLY OWNED UTILITY FACILITIES We hold joint ownership interests in certain electric generating facilities. We are entitled to our share of generating capability and output of each facility equal to our respective ownership interest. We pay our ownership share of additional construction costs and have supplied our own financing for all jointly owned projects. We record our proportionate share of significant jointly owned electric generating facilities as property, plant, and equipment on the balance sheets. In addition, our proportionate share of direct expenses for the joint operation of these plants is recorded within operating expenses in the income statements. In January 2023, we, along with WE, completed the acquisition of Whitewater, a commercially operational 236.5 MW dual fueled (natural gas and low sulfur fuel oil) combined cycle electric generation facility. We own 50% of this facility. See Note 2, Acquisitions, for more information. In April 2023, we, along with an unaffiliated utility, completed the acquisition of Red Barn, a commercially operational utility-scale wind-powered electric generating facility. We own 90%, or 82 MWs, of Red Barn. See Note 2, Acquisitions, for more information. |
COMMON EQUITY
COMMON EQUITY | 9 Months Ended |
Sep. 30, 2023 | |
Equity [Abstract] | |
COMMON EQUITY | COMMON EQUITY Various financing arrangements and regulatory requirements impose certain restrictions on our ability to transfer funds to the sole holder of our common stock, Integrys, in the form of cash dividends, loans, or advances. In addition, Wisconsin law prohibits us from making loans to or guaranteeing obligations of WEC Energy Group, Integrys, or their subsidiaries. See Note 11, Common Equity, in our 2022 Annual Report on Form 10-K for additional information on these and other restrictions. We do not believe that these restrictions will materially affect our operations or limit any dividend payments in the foreseeable future. |
SHORT-TERM DEBT AND LINES OF CR
SHORT-TERM DEBT AND LINES OF CREDIT | 9 Months Ended |
Sep. 30, 2023 | |
Short-Term Debt [Abstract] | |
SHORT-TERM DEBT AND LINES OF CREDIT | SHORT-TERM DEBT AND LINES OF CREDIT The following table shows our short-term borrowings and their corresponding weighted-average interest rates: (in millions, except percentages) September 30, 2023 December 31, 2022 Commercial paper Amount outstanding $ 131.0 $ 194.9 Weighted-average interest rate on amounts outstanding 5.38 % 4.60 % Our average amount of commercial paper borrowings based on daily outstanding balances during the nine months ended September 30, 2023 was $146.7 million with a weighted-average interest rate during the period of 5.09%. The information in the table below relates to our revolving credit facility used to support our commercial paper borrowing program, including available capacity under this facility: (in millions) Maturity September 30, 2023 Revolving credit facility September 2026 $ 400.0 Less: Letters of credit issued inside credit facility $ 1.3 Commercial paper outstanding 131.0 Available capacity under existing credit facility $ 267.7 |
LEASES
LEASES | 9 Months Ended |
Sep. 30, 2023 | |
Lessee Disclosure [Abstract] | |
LEASES | LEASES Obligations Under Finance Leases Land Leases – Utility Solar Generation We, along with WE and an unaffiliated utility, partnered to acquire and construct Darien, a utility-scale solar-powered electric generating facility in Rock and Walworth counties, Wisconsin. We own 15% of Darien. Commercial operation of the project is targeted in 2024. Related to our investment in Darien, we, along with WE and an unaffiliated utility, entered into several land leases that commenced in the second quarter of 2023. Each lease has an initial construction term that ends upon achieving commercial operation, then automatically extends for 25 years with an option for an additional 25-year extension. We expect the optional extension to be exercised, and, as a result, the land leases are being amortized over the extended term of the leases. Once Darien achieves commercial operation, the lease liability will be remeasured to reflect the final total acres being leased. The lease payments will be recovered through rates. Our total obligation under the land-related finance leases for Darien was $6.7 million at September 30, 2023, and was included in long-term debt on the balance sheet. Our finance lease right of use asset related to Darien was $6.5 million as of September 30, 2023, and was included in property, plant, and equipment on our balance sheet. In accordance with ASC Subtopic 980-842, Regulated Operations – Leases (Subtopic 980-842), the expense recognition pattern associated with the Darien leases resembles that of an operating lease. The difference between the minimum lease payments and the sum of imputed interest and unadjusted amortization costs calculated under Topic 842 is deferred as a regulatory asset on our balance sheet in accordance with Subtopic 980-842. At September 30, 2023, our weighted-average discount rate for the Darien finance leases was 5.96%. We used the fully collateralized incremental borrowing rates based upon information available for similarly rated companies in determining the present value of lease payments. Future minimum lease payments and the corresponding present value of our net minimum lease payments under the finance leases for Darien as of September 30, 2023, were as follows: (in millions) Three months ended December 31, 2023 $ — 2024 0.1 2025 0.3 2026 0.3 2027 0.3 2028 0.4 Thereafter 26.3 Total minimum lease payments 27.7 Less: Interest (21.0) Present value of minimum lease payments 6.7 Less: Short-term lease liabilities — Long-term lease liabilities $ 6.7 |
MATERIALS, SUPPLIES, AND INVENT
MATERIALS, SUPPLIES, AND INVENTORIES | 9 Months Ended |
Sep. 30, 2023 | |
Inventory Disclosure [Abstract] | |
MATERIALS, SUPPLIES, AND INVENTORIES | MATERIALS, SUPPLIES, AND INVENTORIES Our inventories consisted of: (in millions) September 30, 2023 December 31, 2022 Materials and supplies $ 75.4 $ 59.3 Natural gas in storage 41.1 65.0 Fossil fuel 39.8 40.2 Total $ 156.3 $ 164.5 Substantially all materials and supplies, natural gas in storage, and fossil fuel inventories are recorded using the weighted-average cost method of accounting. |
INCOME TAXES
INCOME TAXES | 9 Months Ended |
Sep. 30, 2023 | |
Income Tax Disclosure [Abstract] | |
INCOME TAXES | INCOME TAXES The provision for income taxes differs from the amount of income tax determined by applying the applicable United States statutory federal income tax rate to income before income taxes as a result of the following: Three Months Ended September 30, 2023 Three Months Ended September 30, 2022 (in millions) Amount Effective Tax Rate Amount Effective Tax Rate Statutory federal income tax $ 22.6 21.0 % $ 16.8 21.0 % State income taxes net of federal tax benefit 6.8 6.3 % 5.1 6.3 % PTCs, net (3.4) (3.2) % — — % Federal excess deferred tax amortization (1.9) (1.8) % (1.3) (1.6) % Federal excess deferred tax amortization – Wisconsin unprotected (1.3) (1.2) % (0.9) (1.1) % ITCs (1.3) (1.2) % (0.7) (0.9) % Other, net (0.1) — % (0.1) (0.1) % Total income tax expense $ 21.4 19.9 % $ 18.9 23.6 % Nine Months Ended September 30, 2023 Nine Months Ended September 30, 2022 (in millions) Amount Effective Tax Rate Amount Effective Tax Rate Statutory federal income tax $ 56.1 21.0 % $ 53.5 21.0 % State income taxes net of federal tax benefit 16.8 6.3 % 16.1 6.3 % PTCs, net (11.0) (4.1) % — — % Federal excess deferred tax amortization (4.8) (1.8) % (4.2) (1.7) % Federal excess deferred tax amortization – Wisconsin unprotected (3.2) (1.2) % (3.1) (1.2) % ITCs (3.2) (1.2) % (2.2) (0.9) % Other, net (0.4) (0.2) % 0.4 0.2 % Total income tax expense $ 50.3 18.8 % $ 60.5 23.7 % The effective tax rates for the three and nine months ended September 30, 2023, differ from the United States statutory federal income tax rate of 21%, primarily due to PTCs and the impact of the protected deferred tax benefits associated with the Tax Legislation, as discussed in more detail below. These items were partially offset by state income taxes. The effective tax rates for the three and nine months ended September 30, 2022, differ from the United States statutory federal income tax rate of 21%, primarily due to state income taxes. This item was partially offset by the impact of the protected deferred tax benefits associated with the Tax Legislation, as discussed in more detail below. The Tax Legislation required us to remeasure the deferred income taxes at our utility segment and we began to amortize the resulting excess protected deferred income taxes beginning in 2018 in accordance with normalization requirements (see federal excess deferred tax amortization lines above). See Note 23, Regulatory Environment, in our 2022 Annual Report on Form 10-K for more information about the impact of the Tax Legislation. The IRA contains a tax credit transferability provision that allows us to sell PTCs produced after December 31, 2022, to third parties. In September 2023, under this transferability provision, WEC Energy Group entered into an agreement to sell substantially all of our 2023 PTCs to a third party. We elect to account for net proceeds received from the sale of PTCs as a reduction to income taxes payable under the scope of ASC 740. We include the discount from the sale of tax credits as a component of income tax expense. We will also include any expected proceeds from the sale of tax credits in the evaluation of the realizability of deferred tax assets related to PTCs. The sale of tax credits will be presented in the operating activities section of the statements of cash flows consistent with the presentation of cash taxes paid. |
FAIR VALUE MEASUREMENTS
FAIR VALUE MEASUREMENTS | 9 Months Ended |
Sep. 30, 2023 | |
Fair Value Disclosures [Abstract] | |
FAIR VALUE MEASUREMENTS | FAIR VALUE MEASUREMENTSFair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). Fair value accounting rules provide a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are defined as follows: Level 1 – Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 2 – Pricing inputs are observable, either directly or indirectly, but are not quoted prices included within Level 1. Level 2 includes those financial instruments that are valued using external inputs within models or other valuation methods. Level 3 – Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methods that result in management's best estimate of fair value. Level 3 instruments include those that may be more structured or otherwise tailored to customers' needs. Assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. We use a mid-market pricing convention (the mid-point price between bid and ask prices) as a practical measure for valuing certain derivative assets and liabilities. We primarily use a market approach for recurring fair value measurements and attempt to use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. When possible, we base the valuations of our derivative assets and liabilities on quoted prices for identical assets and liabilities in active markets. These valuations are classified in Level 1. The valuations of certain contracts not classified as Level 1 may be based on quoted market prices received from counterparties and/or observable inputs for similar instruments. Transactions valued using these inputs are classified in Level 2. Certain derivatives, such as FTRs, are categorized in Level 3 due to the significance of unobservable or internally-developed inputs. Our FTRs are valued using MISO auction prices. The following tables summarize our financial assets and liabilities that were accounted for at fair value on a recurring basis, categorized by level within the fair value hierarchy: September 30, 2023 (in millions) Level 1 Level 2 Level 3 Total Derivative assets Natural gas contracts $ 0.3 $ 0.6 $ — $ 0.9 FTRs — — 3.9 3.9 Coal contracts — 0.7 — 0.7 Total derivative assets $ 0.3 $ 1.3 $ 3.9 $ 5.5 Derivative liabilities Natural gas contracts $ 10.1 $ 0.2 $ — $ 10.3 Coal contracts — 0.6 — 0.6 Total derivative liabilities $ 10.1 $ 0.8 $ — $ 10.9 December 31, 2022 (in millions) Level 1 Level 2 Level 3 Total Derivative assets Natural gas contracts $ 1.2 $ 0.5 $ — $ 1.7 FTRs — — 4.1 4.1 Coal contracts — 1.8 — 1.8 Total derivative assets $ 1.2 $ 2.3 $ 4.1 $ 7.6 Derivative liabilities Natural gas contracts $ 14.5 $ 2.4 $ — $ 16.9 The derivative assets and liabilities listed in the tables above include options, futures, physical commodity contracts, and other instruments used to manage market risks related to changes in commodity prices. They also include FTRs, which are used to manage electric transmission congestion costs in the MISO Energy and Operating Reserves Markets. The following table summarizes the changes to derivatives classified as Level 3 in the fair value hierarchy: Three Months Ended September 30 Nine Months Ended September 30 (in millions) 2023 2022 2023 2022 Balance at the beginning of the period $ 5.7 $ 10.3 $ 4.1 $ 1.4 Purchases — 0.1 6.3 11.7 Settlements (1.8) (4.0) (6.5) (6.7) Balance at the end of the period $ 3.9 $ 6.4 $ 3.9 $ 6.4 Fair Value of Financial Instruments The following table shows the financial instruments included on our balance sheets that were not recorded at fair value: September 30, 2023 December 31, 2022 (in millions) Carrying Amount Fair Value Carrying Amount Fair Value Long-term debt (1) $ 1,958.8 $ 1,512.6 $ 1,958.0 $ 1,607.2 (1) The carrying amount of long-term debt excludes finance lease obligations of $49.0 million and $41.9 million at September 30, 2023 and December 31, 2022, respectively. The fair value of our long-term debt is categorized within Level 2 of the fair value hierarchy. |
DERIVATIVE INSTRUMENTS
DERIVATIVE INSTRUMENTS | 9 Months Ended |
Sep. 30, 2023 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
DERIVATIVE INSTRUMENTS | DERIVATIVE INSTRUMENTS We use derivatives as part of our risk management program to manage the risks associated with the price volatility of purchased power, generation, and natural gas costs for the benefit of our customers. Our approach is non-speculative and designed to mitigate risk. Our regulated hedging programs are approved by the PSCW. We record derivative instruments on our balance sheets as an asset or liability measured at fair value unless they qualify for the normal purchases and sales exception and are so designated. We continually assess our contracts designated as normal and will discontinue the treatment of these contracts as normal if the required criteria are no longer met. Changes in the derivative's fair value are recognized currently in earnings unless specific hedge accounting criteria are met or we receive regulatory treatment for the derivative. For most energy-related physical and financial contracts in our regulated operations that qualify as derivatives, the PSCW allows the effects of fair value accounting to be offset to regulatory assets and liabilities. On our balance sheets, we classify derivative assets and liabilities as current or long-term based on the maturities of the underlying contracts. Derivative assets and liabilities are included in the other current and other long-term line items on our balance sheets. The following table shows our derivative assets and derivative liabilities. None of the derivatives shown below are designated as hedging instruments. September 30, 2023 December 31, 2022 (in millions) Derivative Assets Derivative Liabilities Derivative Assets Derivative Liabilities Current Natural gas contracts $ 0.9 $ 10.2 $ 1.7 $ 16.3 FTRs 3.9 — 4.1 — Coal contracts 0.6 0.4 1.4 — Total current 5.4 10.6 7.2 16.3 Long-term Natural gas contracts — 0.1 — 0.6 Coal contracts 0.1 0.2 0.4 — Total long-term 0.1 0.3 0.4 0.6 Total $ 5.5 $ 10.9 $ 7.6 $ 16.9 Realized gains and losses on derivatives are primarily recorded in cost of sales Three Months Ended September 30, 2023 Three Months Ended September 30, 2022 (in millions) Volumes Gains (Losses) Volumes Gains Natural gas contracts 7.4 Dth $ (11.4) 5.4 Dth $ 16.6 FTRs 2.2 MWh 8.1 2.0 MWh 1.6 Total $ (3.3) $ 18.2 Nine Months Ended September 30, 2023 Nine Months Ended September 30, 2022 (in millions) Volumes Gains (Losses) Volumes Gains Natural gas contracts 29.0 Dth $ (40.2) 24.5 Dth $ 38.2 FTRs 6.4 MWh 10.8 6.0 MWh 2.3 Total $ (29.4) $ 40.5 On our balance sheets, the amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral are not offset against the fair value amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement. At September 30, 2023 and December 31, 2022, we had posted cash collateral of $21.8 million and $26.6 million, respectively. These amounts were recorded on our balance sheets as collateral on deposit. The following table shows derivative assets and derivative liabilities if derivative instruments by counterparty were presented net on our balance sheets: September 30, 2023 December 31, 2022 (in millions) Derivative Assets Derivative Liabilities Derivative Assets Derivative Liabilities Gross amount recognized on the balance sheet $ 5.5 $ 10.9 $ 7.6 $ 16.9 Gross amount not offset on the balance sheet (0.4) (10.3) (1) (1.4) (14.8) (2) Net amount $ 5.1 $ 0.6 $ 6.2 $ 2.1 (1) Includes cash collateral posted of $9.9 million. |
GUARANTEES
GUARANTEES | 9 Months Ended |
Sep. 30, 2023 | |
Guarantees [Abstract] | |
GUARANTEES | GUARANTEESAs of September 30, 2023, we had $20.6 million of standby letters of credit issued by financial institutions for the benefit of third parties that have extended credit to us, which automatically renew each year unless proper termination notice is given. These amounts are not reflected on our balance sheets. |
EMPLOYEE BENEFITS
EMPLOYEE BENEFITS | 9 Months Ended |
Sep. 30, 2023 | |
Retirement Benefits [Abstract] | |
EMPLOYEE BENEFITS | EMPLOYEE BENEFITS The following tables show the components of net periodic benefit cost (credit) (including amounts capitalized to our balance sheets) for our benefit plans. Pension Benefits Three Months Ended September 30 Nine Months Ended September 30 (in millions) 2023 2022 2023 2022 Service cost $ 1.2 $ 2.3 $ 3.6 $ 6.8 Interest cost 7.5 5.7 22.6 17.0 Expected return on plan assets (12.8) (13.8) (38.5) (41.4) Amortization of net actuarial loss 4.3 4.3 13.0 13.0 Net periodic benefit cost (credit) $ 0.2 $ (1.5) $ 0.7 $ (4.6) OPEB Benefits Three Months Ended September 30 Nine Months Ended September 30 (in millions) 2023 2022 2023 2022 Service cost $ 0.6 $ 1.0 $ 2.0 $ 3.0 Interest cost 1.5 1.0 4.6 3.2 Expected return on plan assets (4.0) (5.2) (12.2) (15.7) Amortization of prior service credit (2.5) (2.5) (7.6) (7.6) Amortization of net actuarial (gain) loss 0.3 (0.6) 0.8 (1.9) Net periodic benefit credit $ (4.1) $ (6.3) $ (12.4) $ (19.0) During the nine months ended September 30, 2023, we made contributions and payments of $0.5 million related to our pension plans and $0.7 million related to our OPEB plans. We expect to make contributions and payments of $0.1 million related to our pension plans and $0.2 million related to our OPEB plans during the remainder of 2023, dependent upon various factors affecting us, including our liquidity position and possible tax law changes. Effective January 1, 2023, the PSCW approved escrow accounting for pension and OPEB costs. As a result, as of September 30, 2023, we recorded a $5.1 million regulatory asset for pension costs and a $5.1 million regulatory asset for OPEB costs. The above tables do not reflect any adjustments for the creation of these regulatory assets. |
GOODWILL AND INTANGIBLE ASSETS
GOODWILL AND INTANGIBLE ASSETS | 9 Months Ended |
Sep. 30, 2023 | |
Goodwill and Intangible Assets Disclosure [Abstract] | |
GOODWILL AND INTANGIBLE ASSETS | GOODWILL AND INTANGIBLE ASSETS Goodwill Goodwill represents the excess of the cost of an acquisition over the fair value of the identifiable net assets acquired. We had no changes to the carrying amount of goodwill during the nine months ended September 30, 2023. We had no accumulated impairment losses related to our goodwill as of September 30, 2023. During the third quarter of 2023, we completed our annual impairment test for goodwill we carried as of July 1, 2023. No impairment resulted from this test. Intangible Assets |
SEGMENT INFORMATION
SEGMENT INFORMATION | 9 Months Ended |
Sep. 30, 2023 | |
Segment Reporting [Abstract] | |
SEGMENT INFORMATION | SEGMENT INFORMATION We use net income to measure segment profitability and to allocate resources to our businesses. At September 30, 2023, we reported two segments, which are described below. Our utility segment includes our electric and natural gas utility operations, which serve customers in northeastern and central Wisconsin. Our electric utility operations are engaged in the generation, distribution, and sale of electricity. Our natural gas utility operations are engaged in the purchase, distribution, and sale of natural gas to retail customers as well as the transportation of customer-owned natural gas. Our other segment primarily consists of equity earnings from our investment in Wisconsin River Power Company. All of our operations and assets are located within the United States. The following tables show summarized financial information for the three and nine months ended September 30, 2023 and 2022, related to our reportable segments: (in millions) Utility Other Wisconsin Public Service Corporation Three months ended September 30, 2023 Operating revenues $ 411.6 $ — $ 411.6 Other operation and maintenance 107.2 — 107.2 Depreciation and amortization 57.5 — 57.5 Other income, net 10.7 0.5 11.2 Interest expense 22.3 — 22.3 Income tax expense 21.3 0.1 21.4 Net income 85.8 0.4 86.2 (in millions) Utility Other Wisconsin Public Service Corporation Three months ended September 30, 2022 Operating revenues $ 435.3 $ — $ 435.3 Other operation and maintenance 89.9 — 89.9 Depreciation and amortization 50.1 — 50.1 Other income, net 10.8 0.2 11.0 Interest expense 17.3 — 17.3 Income tax expense 18.8 0.1 18.9 Net income 61.1 0.1 61.2 (in millions) Utility Other Wisconsin Public Service Corporation Nine months ended September 30, 2023 Operating revenues $ 1,284.1 $ — $ 1,284.1 Other operation and maintenance 320.5 — 320.5 Depreciation and amortization 168.7 — 168.7 Other income, net 33.8 1.8 35.6 Interest expense 66.3 — 66.3 Income tax expense 49.9 0.4 50.3 Net income 215.2 1.4 216.6 (in millions) Utility Other Wisconsin Public Service Corporation Nine months ended September 30, 2022 Operating revenues $ 1,332.7 $ — $ 1,332.7 Other operation and maintenance 268.0 — 268.0 Depreciation and amortization 149.3 — 149.3 Other income, net 31.7 1.0 32.7 Interest expense 50.5 — 50.5 Income tax expense 60.2 0.3 60.5 Net income 193.7 0.7 194.4 |
COMMITMENTS AND CONTINGENCIES
COMMITMENTS AND CONTINGENCIES | 9 Months Ended |
Sep. 30, 2023 | |
Commitments and Contingencies Disclosure [Abstract] | |
COMMITMENTS AND CONTINGENCIES | COMMITMENTS AND CONTINGENCIES We have significant commitments and contingencies arising from our operations, including those related to unconditional purchase obligations, environmental matters, and enforcement and litigation matters. Unconditional Purchase Obligations We have obligations to distribute and sell electricity and natural gas to our customers and expect to recover costs related to these obligations in future customer rates. In order to meet these obligations, we routinely enter into long-term purchase and sale commitments for various quantities and lengths of time. Our minimum future commitments related to these purchase obligations as of September 30, 2023, were approximately $1 billion. Environmental Matters Consistent with other companies in the energy industry, we face significant ongoing environmental compliance and remediation obligations related to current and past operations. Specific environmental issues affecting us include, but are not limited to, current and future regulation of air emissions such as sulfur dioxide, NOx, fine particulates, mercury, and GHGs; water intake and discharges; management of coal combustion products such as fly ash; and remediation of impacted properties, including former manufactured gas plant sites. Air Quality Cross State Air Pollution Rule – Good Neighbor Plan In March 2023, the EPA issued its final Good Neighbor Plan, which became effective in August 2023 and requires significant reductions in ozone-forming emissions of NOx from power plants and industrial facilities. After review of the final rule, we believe that we are well positioned to meet the requirements. Our RICE units in Wisconsin are not currently subject to the final rule as each unit is less than 25 MWs. To the extent we use RICE engines for natural gas distribution operations, those engines not part of an LDC are subject to the emission limits and operational requirements of the rule beginning in 2026. The EPA has exempted LDCs from the final rule. Mercury and Air Toxics Standards In 2012, the EPA issued the MATS to limit emissions of mercury, acid gases, and other hazardous air pollutants. In April 2023, the EPA issued the pre-publication version of a proposed rule to strengthen and update MATS to reflect recent developments in control technologies and performance of coal and oil-fired units. The EPA proposed three revisions including a proposal to lower the PM limit from 0.03 lb/MMBtu to 0.01 lb/MMBtu. The EPA also sought comments on an even lower limit of 0.006 lb/MMBtu. Adoption of either of these lower limits could have an adverse effect on our operations. National Ambient Air Quality Standards Ozone After completing its review of the 2008 ozone standard, the EPA released a final rule in October 2015, creating a more stringent standard than the 2008 NAAQS. The 2015 ozone standard lowered the 8-hour limit for ground-level ozone. In November 2022, the EPA's 2022 CASAC Ozone Review Panel issued a draft report supporting the reconsideration of the 2015 standard. The EPA staff issued a draft Policy Assessment in March 2023 that also supported the reconsideration. Although initially targeting the end of 2023 for completing its reconsideration, the EPA announced in August 2023 that it is instead restarting its ozone standard evaluation. The EPA has indicated it plans to release its Integrated Review Plan in fall 2024. This new review is anticipated to take 3 to 5 years to complete. In February 2022, revisions to the Wisconsin Administrative Code to adopt the 2015 standard were finalized. The amended regulations incorporated by reference the federal air pollution monitoring requirements related to the standard. The WDNR submitted the rule updates as a SIP revision to the EPA, which the EPA approved in February 2023. We believe that we are well positioned to meet the requirements associated with the 2015 ozone standard and do not expect to incur significant costs to comply with the associated state and federal rules. Particulate Matter In December 2020, the EPA completed its 5-year review of the 2012 annual and 24-hour standards for fine PM and determined that no revisions were necessary to the current annual standard of 12 µg/m 3 or the 24-hour standard of 35 µg/m 3 . Under the Biden Administration's policy review, the EPA concluded that the scientific evidence and information from the December 2020 determination supports revising the level of the annual standard for the PM NAAQS to below the current level of 12 µg/m 3 , while retaining the 24-hour standard. In January 2023, the EPA announced its proposed decision to revise the primary (health-based) annual PM2.5 standard from its current level of 12 µg/m 3 to within the range of 9 to 10 µg/m 3 . The EPA also proposed not to change the current secondary (welfare-based) annual PM2.5 standard, primary and secondary 24-hour PM2.5 standards, and primary and secondary PM10 standards. The EPA did, however, take comments on the full range (between 8 and 11 µg/m 3 ) included in the CASAC's latest report. All counties within our service territory are in attainment with the current 2012 standards. If the EPA lowers the annual standard to 10 or 11 µg/m 3 , our generating facilities within our service territory should remain in attainment. If the EPA lowers it to below 10 µg/m 3 , there could be some nonattainment areas that may affect permitting of some smaller ancillary equipment located at our facilities. After finalization of the rule, the WDNR will need to draft and submit a SIP for the EPA's approval. A final rule is anticipated in late 2023 or early 2024. Climate Change In May 2023, the EPA proposed GHG performance standards for existing fossil-fired steam generating and gas combustion units and also proposed to repeal the Affordable Clean Energy rule, which replaced the Clean Power Plan. For coal plants, there are no applicable standards until 2032, and after 2032 the applicable standard is dependent on the unit's retirement date. For combined cycle natural gas plants above a 50% capacity factor, the rule is highly dependent on hydrogen as an alternative fuel, or carbon capture. For simple cycle natural gas-fired combustion turbines, there are no applicable limits as long as the capacity factor is less than 20%. The new Weston RICE project is not affected under the rule because each RICE unit is less than 25 MWs. We are evaluating the proposed rule to understand the impacts to our operations. In May 2023, the EPA proposed to revise the New Source Performance Standards for GHG emissions from new, modified, and reconstructed fossil-fueled power plants. The EPA is proposing two distinct 111(b) rules – one for natural gas-fired stationary combustion turbines and the other for coal-fired units. New stationary combustion turbine units would be divided into three subcategories based on their annual capacity factor – low load, intermediate load, and base load. Our RICE units are not affected by this rule since each unit is below 25 MWs. WEC Energy Group's ESG Progress Plan is heavily focused on reducing GHG emissions. The EPA has indicated that it anticipates a final rule in the second quarter of 2024. The EPA released proposed regulations for the Mandatory Greenhouse Gas Reporting Rule, 40 Code of Federal Regulations Part 98, in June 2022. In May 2023, the EPA released a supplementary proposal, which includes updates of the global warming potentials to determine CO 2 equivalency for threshold reporting and the addition of a new section regarding energy consumption. The proposed revisions could impact the reporting required for our electric generation facilities and local natural gas distribution company. In August 2023, the EPA also issued its proposed updates to amend reporting requirements for petroleum and natural gas systems, with an anticipated final rule to be issued in early 2024. We are currently evaluating the potential impact of the proposed rule, if any, on our operations. The ESG Progress Plan includes the retirement of older, fossil-fueled generation, to be replaced with zero-carbon-emitting renewables and clean natural gas-fueled generation. We have already retired approximately 400 MWs of fossil-fueled generation since the beginning of 2018. Through its ESG Progress Plan, WEC Energy Group expects to retire approximately 1,500 MWs of additional fossil-fueled generation by the end of 2026, which includes the planned retirement by June 2026 of jointly-owned Columbia Units 1 and 2. See Note 6, Property, Plant, and Equipment, for more information on the timing of the retirement. In May 2021, WEC Energy Group announced goals to achieve reductions in carbon emissions from its electric generation fleet by 60% by the end of 2025 and by 80% by the end of 2030, both from a 2005 baseline. WEC Energy Group expects to achieve these goals by making operating refinements, retiring less efficient generating units, and executing its capital plan. Over the longer term, the target for WEC Energy Group's generation fleet is net-zero CO 2 emissions by 2050. WEC Energy Group also continues to reduce methane emissions by improving its natural gas distribution systems, and has set a target across its natural gas distribution operations to achieve net-zero methane emissions by the end of 2030. WEC Energy Group plans to achieve its net-zero goal through an effort that includes both continuous operational improvements and equipment upgrades, as well as the use of RNG throughout its utility systems. Water Quality Clean Water Act Cooling Water Intake Structure Rule The EPA issued a final regulation under Section 316(b) of the CWA that became effective in October 2014 and requires the location, design, construction, and capacity of cooling water intake structures at existing power plants reflect the BTA for minimizing adverse environmental impacts. The rule applies to all of our existing generating facilities with cooling water intake structures. Pursuant to a WDNR rule, which became effective in June 2020, the requirements of federal Section 316(b) of the CWA were incorporated into the Wisconsin Administrative Code. The WDNR applies this rule when establishing BTA requirements for cooling water intake structures at existing facilities. These BTA requirements are incorporated into WPDES permits for our facilities. We have received interim BTA determinations for Weston Units 3 and 4. We believe that existing technology installed at the Weston facility will result in a final BTA determination during the WPDES permit reissuance expected in January 2024. Steam Electric Effluent Limitation Guidelines The EPA's ELG rule, effective January 2016 and modified in 2020, revised the treatment technology requirements related to BATW at existing coal-fueled facilities and created new requirements for several types of power plant wastewaters. The new requirement that affects our facilities relates to discharge limits for BATW. Although our power plant facilities already have advanced wastewater treatment technologies installed that meet many of the discharge limits established by this rule, certain facility modifications are necessary to meet the ELG rule requirements. We completed $8 million of BATW modifications at Weston Unit 3 in June 2023, which are now in service and did not require PSCW approval prior to construction. In March 2023, the EPA issued the proposed "supplemental ELG rule." The rule would replace the existing 2020 ELG rule and, as proposed, would establish stricter limitations on: 1) BATW; 2) flue gas desulfurization wastewater; 3) CCR leachate; and 4) legacy wastewaters. If the supplemental ELG rule is finalized as proposed, we anticipate that our coal-fueled facilities, including Weston Unit 3, will meet the BATW rule provisions. The EPA also proposed requirements for legacy wastewaters and landfill leachate. We are reviewing those proposed requirements to determine potential costs and actions required for our facilities. Waters of the United States In January 2023, the EPA and the Army Corps (the agencies) together released a final rule effective in March 2023, that based the definition of WOTUS on its pre-2015 definition. The pre-2015 approach involved applying factors established through case law and agency precedents to determine whether a wetland or surface drainage feature is subject to federal jurisdiction. In May 2023, in Sackett v. EPA, the Supreme Court issued a decision significantly narrowing federal jurisdiction over wetlands to "traditional navigable waters" and wetlands or other waters that have a "continuous surface connection" with a traditional navigable water. In August 2023, the agencies revised the final rule to conform the definition of WOTUS to the Supreme Court's May 2023 Sackett decision. The conforming rule became effective upon publication in the Federal Register on September 8, 2023. We anticipate this final rule revision caused by the Sackett decision will cause a decrease in the number of projects that require Army Corps federal wetland permits. This decision also may affect the administration of some state programs. At this point, our projects requiring federal permits are moving ahead, but we are monitoring these recent developments to better understand potential future impacts. Land Quality Manufactured Gas Plant Remediation We have identified sites at which we or a predecessor company owned or operated a manufactured gas plant or stored manufactured gas. We have also identified other sites that may have been impacted by historical manufactured gas plant activities. We are responsible for the environmental remediation of these sites, some of which are in the EPA Superfund Alternative Approach Program. We are also working with the state of Wisconsin in our investigation and remediation planning. These sites are at various stages of investigation, monitoring, remediation, and closure. In addition, we are coordinating the investigation and cleanup of some of these sites subject to the jurisdiction of the EPA under what is called a "multisite" program. This program involves prioritizing the work to be done at the sites, preparation and approval of documents common to all of the sites, and use of a consistent approach in selecting remedies. At this time, we cannot estimate future remediation costs associated with these sites beyond those described below. The future costs for detailed site investigation, future remediation, and monitoring are dependent upon several variables including, among other things, the extent of remediation, changes in technology, and changes in regulation. Historically, our regulators have allowed us to recover incurred costs, net of insurance recoveries and recoveries from potentially responsible parties, associated with the remediation of manufactured gas plant sites. Accordingly, we have established regulatory assets for costs associated with these sites. We have established the following regulatory assets and reserves for manufactured gas plant sites: (in millions) September 30, 2023 December 31, 2022 Regulatory assets $ 114.9 $ 118.5 Reserves for future environmental remediation 78.5 88.6 Coal Combustion Residuals Rule The EPA issued a pre-publication proposed rule for CCR in May 2023, that would apply to all landfills, historic fill sites, and projects where CCR was placed. As proposed, the rule would regulate previously exempt closed landfills and would include sites we own as well as several third party owned properties. We are actively engaged with the Utility Solid Waste Activities Group and the Edison Electric Institute and provided them information to include in their comments to the EPA. The EPA has indicated that it is anticipating the rule to be final in the second quarter of 2024. The proposed rule could have a material adverse impact on our coal ash landfills and require additional remediation that has not been required under the current state programs. Enforcement and Litigation Matters We are involved in legal and administrative proceedings before various courts and agencies with respect to matters arising in the ordinary course of business. Although we are unable to predict the outcome of these matters, management believes that appropriate reserves have been established and that final settlement of these actions will not have a material impact on our financial condition or results of operations. Consent Decrees Weston and Pulliam Power Plants In November 2009, the EPA issued an NOV to us, which alleged violations of the CAA's New Source Review requirements relating to certain projects completed at the Weston and Pulliam power plants from 1994 to 2009. We entered into a Consent Decree with the EPA resolving this NOV. This Consent Decree was entered by the United States District Court for the Eastern District of Wisconsin in March 2013. With the retirement of Pulliam Units 7 and 8 in October 2018, we completed the mitigation projects required by the Consent Decree and received a completeness letter from the EPA in October 2018. We are working with the EPA on a closeout process for the Consent Decree and expect that process to begin later in 2023. Joint Ownership Power Plants – Columbia and Edgewater In December 2009, the EPA issued an NOV to Wisconsin Power and Light Company, the operator of the Columbia and Edgewater plants, and the other joint owners of these plants, including Madison Gas and Electric Company, WE (former co-owner of an Edgewater unit), and us. The NOV alleged violations of the CAA's New Source Review requirements related to certain projects completed at those plants. We, along with Wisconsin Power and Light Company, Madison Gas and Electric Company, and WE, |
SUPPLEMENTAL CASH FLOW INFORMAT
SUPPLEMENTAL CASH FLOW INFORMATION | 9 Months Ended |
Sep. 30, 2023 | |
Supplemental Cash Flow Information [Abstract] | |
SUPPLEMENTAL CASH FLOW INFORMATION | SUPPLEMENTAL CASH FLOW INFORMATION Non-Cash Transactions Nine Months Ended September 30 (in millions) 2023 2022 Cash paid for interest, net of amount capitalized $ 49.8 $ 39.1 Cash paid for income taxes, net 8.3 20.7 Significant non-cash investing and financing transactions: Accounts payable related to construction costs 28.4 33.1 Payable for the transfer of assets from WE 2.4 — Liabilities accrued for software licensing agreement — 1.5 Restricted Cash The statements of cash flows include our activity related to cash, cash equivalents, and restricted cash. The following table reconciles the cash, cash equivalents, and restricted cash amounts reported within the balance sheets to the total of these amounts shown on the statements of cash flows: (in millions) September 30, 2023 December 31, 2022 Cash and cash equivalents $ 1.5 $ 0.5 Restricted cash included in other long-term assets — 38.0 Cash, cash equivalents, and restricted cash $ 1.5 $ 38.5 At December 31, 2022, our restricted cash consisted of cash used during January 2023 to purchase a 50% interest in a natural gas-fired cogeneration facility located in Whitewater, Wisconsin. This cash was included in other long-term assets. See Note 2, Acquisitions, for more information. |
REGULATORY ENVIRONMENT
REGULATORY ENVIRONMENT | 9 Months Ended |
Sep. 30, 2023 | |
Regulated Operations [Abstract] | |
REGULATORY ENVIRONMENT | REGULATORY ENVIRONMENT 2024 Limited Rate Case Re-Opener In accordance with our rate order approved by the PSCW in December 2022, we filed a request with the PSCW in May 2023 for a limited electric rate case re-opener. The request includes an $8.6 million (0.5%) increase in 2024 base rates to reflect updated revenue requirements for the generation projects that were previously approved by the PSCW and are expected to be placed into service in 2023 and 2024. Our ROE and common equity component average will not be addressed in the limited rate case re-opener. A PSCW decision is expected in the fourth quarter of 2023, with new rates expected to be effective January 1, 2024. |
NEW ACCOUNTING PRONOUCEMENTS
NEW ACCOUNTING PRONOUCEMENTS | 9 Months Ended |
Sep. 30, 2023 | |
Accounting Changes and Error Corrections [Abstract] | |
NEW ACCOUNTING PRONOUNCEMENTS | NEW ACCOUNTING PRONOUNCEMENTS Reference Rate Reform In March 2020, the FASB issued ASU No. 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting and in January 2021, the FASB issued ASU No. 2021-01, Reference Rate Reform (Topic 848): Scope. These pronouncements provide temporary optional expedients and exceptions for applying GAAP principles to contract modifications and hedging relationships to ease the financial reporting burdens of the market transition from LIBOR and other interbank offered rates to alternative reference rates. These pronouncements were effective upon issuance on March 12, 2020 through December 31, 2022. In December 2022, the FASB issued ASU No. 2022-06, Reference Rate Reform (Topic 848): Deferral of the Sunset Date of Topic 848, to extend the temporary accounting rules under Topic 848 from December 31, 2022 to December 31, 2024, after which entities will no longer be permitted to apply the relief in Topic 848. An entity may elect to apply the amendments prospectively from March 12, 2020 through December 31, 2024 by accounting topic. We do not anticipate this guidance having a significant impact on our financial statements and related disclosures. |
Pay vs Performance Disclosure
Pay vs Performance Disclosure - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Pay vs Performance Disclosure | ||||
Net income | $ 86.2 | $ 61.2 | $ 216.6 | $ 194.4 |
Insider Trading Arrangements
Insider Trading Arrangements | 3 Months Ended |
Sep. 30, 2023 | |
Trading Arrangements, by Individual | |
Rule 10b5-1 Arrangement Adopted | false |
Non-Rule 10b5-1 Arrangement Adopted | false |
Rule 10b5-1 Arrangement Terminated | false |
Non-Rule 10b5-1 Arrangement Terminated | false |
GENERAL INFORMATION (Policies)
GENERAL INFORMATION (Policies) | 9 Months Ended |
Sep. 30, 2023 | |
Accounting policies | |
Basis of accounting | As used in these notes, the term "financial statements" refers to the condensed financial statements. This includes the income statements, balance sheets, statements of cash flows, and statements of equity, unless otherwise noted. In this report, when we refer to "the Company," "us," "we," "our," or "ours," we are referring to Wisconsin Public Service Corporation. We have prepared the unaudited interim financial statements presented in this Form 10-Q pursuant to the rules and regulations of the SEC and GAAP. Accordingly, these financial statements do not include all of the information and footnotes required by GAAP for annual financial statements. These financial statements should be read in conjunction with the financial statements and footnotes in our Annual Report on Form 10-K for the year ended December 31, 2022. Financial results for an interim period may not give a true indication of results for the year. In particular, the results of operations for the three and nine months ended September 30, 2023, are not necessarily indicative of expected results for 2023 due to seasonal variations and other factors. In management's opinion, we have included all adjustments, normal and recurring in nature, necessary for a fair presentation of our financial results. |
Equity method investments | Investments in companies not controlled by us, but over which we have significant influence regarding the operating and financial policies of the investee, are accounted for using the equity method. |
Credit losses | Our exposure to credit losses is related to our accounts receivable and unbilled revenue balances, which are generated from the sale of electricity and natural gas by our regulated utility operations. Our regulated utility operations are included in our utility segment. No accounts receivable and unbilled revenue balances were reported in the other segment at September 30, 2023 and December 31, 2022. We evaluate the collectability of our accounts receivable and unbilled revenue balances considering a combination of factors. For some of our larger customers and also in circumstances where we become aware of a specific customer's inability to meet its financial obligations to us, we record a specific allowance for credit losses against amounts due in order to reduce the net recognized receivable to the amount we reasonably believe will be collected. For all other customers, we use the accounts receivable aging method to calculate an allowance for credit losses. Using this method, we classify accounts receivable into different aging buckets and calculate a reserve percentage for each aging bucket based upon historical loss rates. The calculated reserve percentages are updated on at least an annual basis, in order to ensure recent macroeconomic, political, and regulatory trends are captured in the calculation, to the extent possible. Risks identified that we do not believe are reflected in the calculated reserve percentages, are assessed on a quarterly basis to determine whether further adjustments are required. We monitor our ongoing credit exposure through active review of counterparty accounts receivable balances against contract terms and due dates. Our activities include timely account reconciliation, dispute resolution and payment confirmation. To the extent possible, we work with customers with past due balances to negotiate payment plans, but will disconnect customers for non-payment as allowed by the PSCW, if necessary, and employ collection agencies and legal counsel to pursue recovery of defaulted receivables. For our larger customers, detailed credit review procedures may be performed in advance of any sales being made. We sometimes require letters of credit, parental guarantees, prepayments or other forms of credit assurance from our larger customers to mitigate credit risk. |
Income taxes | We elect to account for net proceeds received from the sale of PTCs as a reduction to income taxes payable under the scope of ASC 740. We include the discount from the sale of tax credits as a component of income tax expense. We will also include any expected proceeds from the sale of tax credits in the evaluation of the realizability of deferred tax assets related to PTCs. |
Fair value measurement | Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). Fair value accounting rules provide a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are defined as follows: Level 1 – Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 2 – Pricing inputs are observable, either directly or indirectly, but are not quoted prices included within Level 1. Level 2 includes those financial instruments that are valued using external inputs within models or other valuation methods. Level 3 – Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methods that result in management's best estimate of fair value. Level 3 instruments include those that may be more structured or otherwise tailored to customers' needs. Assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. We use a mid-market pricing convention (the mid-point price between bid and ask prices) as a practical measure for valuing certain derivative assets and liabilities. We primarily use a market approach for recurring fair value measurements and attempt to use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. |
Derivative instruments | We use derivatives as part of our risk management program to manage the risks associated with the price volatility of purchased power, generation, and natural gas costs for the benefit of our customers. Our approach is non-speculative and designed to mitigate risk. Our regulated hedging programs are approved by the PSCW. We record derivative instruments on our balance sheets as an asset or liability measured at fair value unless they qualify for the normal purchases and sales exception and are so designated. We continually assess our contracts designated as normal and will discontinue the treatment of these contracts as normal if the required criteria are no longer met. Changes in the derivative's fair value are recognized currently in earnings unless specific hedge accounting criteria are met or we receive regulatory treatment for the derivative. For most energy-related physical and financial contracts in our regulated operations that qualify as derivatives, the PSCW allows the effects of fair value accounting to be offset to regulatory assets and liabilities. |
New accounting pronouncements | Reference Rate Reform In March 2020, the FASB issued ASU No. 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting and in January 2021, the FASB issued ASU No. 2021-01, Reference Rate Reform (Topic 848): Scope. These pronouncements provide temporary optional expedients and exceptions for applying GAAP principles to contract modifications and hedging relationships to ease the financial reporting burdens of the market transition from LIBOR and other interbank offered rates to alternative reference rates. These pronouncements were effective upon issuance on March 12, 2020 through December 31, 2022. In December 2022, the FASB issued ASU No. 2022-06, Reference Rate Reform (Topic 848): Deferral of the Sunset Date of Topic 848, to extend the temporary accounting rules under Topic 848 from December 31, 2022 to December 31, 2024, after which entities will no longer be permitted to apply the relief in Topic 848. An entity may elect to apply the amendments prospectively from March 12, 2020 through December 31, 2024 by accounting topic. We do not anticipate this guidance having a significant impact on our financial statements and related disclosures. |
OPERATING REVENUES (Tables)
OPERATING REVENUES (Tables) - Utility segment | 9 Months Ended |
Sep. 30, 2023 | |
Disaggregation of Operating Revenues | |
Operating revenues disaggregated by revenue source | The following tables present our operating revenues disaggregated by revenue source for our utility segment. We do not have any revenues associated with our other segment. We disaggregate revenues into categories that depict how the nature, amount, timing, and uncertainty of revenues and cash flows are affected by economic factors. Revenues are further disaggregated by electric and natural gas operations and then by customer class. Each customer class within our electric and natural gas operations has different expectations of service, energy and demand requirements, and can be impacted differently by regulatory activities within their jurisdictions. Three Months Ended September 30 Nine Months Ended September 30 (in millions) 2023 2022 2023 2022 Wisconsin Public Service Corporation Electric utility $ 370.1 $ 373.0 $ 1,009.9 $ 1,016.3 Natural gas utility 40.9 61.7 272.3 312.9 Total revenues from contracts with customers 411.0 434.7 1,282.2 1,329.2 Other operating revenues 0.6 0.6 1.9 3.5 Total operating revenues $ 411.6 $ 435.3 $ 1,284.1 $ 1,332.7 |
Revenues from contracts with customers | Electric | |
Disaggregation of Operating Revenues | |
Operating revenues disaggregated by revenue source | The following table disaggregates electric utility operating revenues by customer class: Three Months Ended September 30 Nine Months Ended September 30 (in millions) 2023 2022 2023 2022 Residential $ 131.1 $ 122.6 $ 365.5 $ 351.0 Small commercial and industrial 130.2 116.8 343.9 318.4 Large commercial and industrial 79.1 87.8 211.9 230.5 Other 2.1 2.2 6.5 6.6 Total retail revenues 342.5 329.4 927.8 906.5 Wholesale 21.2 28.1 63.8 73.6 Resale 4.4 9.1 14.7 21.2 Other utility revenues 2.0 6.4 3.6 15.0 Total electric utility operating revenues $ 370.1 $ 373.0 $ 1,009.9 $ 1,016.3 |
Revenues from contracts with customers | Natural gas | |
Disaggregation of Operating Revenues | |
Operating revenues disaggregated by revenue source | The following table disaggregates natural gas utility operating revenues by customer class: Three Months Ended September 30 Nine Months Ended September 30 (in millions) 2023 2022 2023 2022 Residential $ 21.2 $ 29.6 $ 167.9 $ 178.6 Commercial and industrial 10.8 22.6 95.6 116.4 Total retail revenues 32.0 52.2 263.5 295.0 Transportation 4.4 3.9 16.2 14.6 Other utility revenues (1) 4.5 5.6 (7.4) 3.3 Total natural gas utility operating revenues $ 40.9 $ 61.7 $ 272.3 $ 312.9 (1) Includes the revenues subject to our purchased gas recovery mechanism, which fluctuate based on actual natural gas costs incurred, compared with the recovery of natural gas costs that were anticipated in rates. |
Other operating revenues | |
Disaggregation of Operating Revenues | |
Operating revenues disaggregated by revenue source | Other operating revenues consist primarily of the following: Three Months Ended September 30 Nine Months Ended September 30 (in millions) 2023 2022 2023 2022 Late payment charges $ 0.8 $ 0.8 $ 3.1 $ 3.0 Alternative revenues (1) (0.3) (0.3) (1.5) 0.2 Other 0.1 0.1 0.3 0.3 Total other operating revenues $ 0.6 $ 0.6 $ 1.9 $ 3.5 (1) Negative amounts can result from alternative revenues being reversed to revenues from contracts with customers as the customer is billed for these alternative revenues. Negative amounts can also result from revenues to be refunded to wholesale customers subject to true-ups, as discussed in Note 1(d), Operating Revenues, in our 2022 Annual Report on Form 10-K. |
CREDIT LOSSES (Tables)
CREDIT LOSSES (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Credit Loss [Abstract] | |
Schedule of gross receivables and related allowances for credit losses | We have included a table below that shows our gross third-party receivable balances and related allowance for credit losses. (in millions) September 30, 2023 December 31, 2022 Accounts receivable and unbilled revenues $ 212.3 $ 279.5 Allowance for credit losses 9.6 11.7 Accounts receivable and unbilled revenues, net (1) $ 202.7 $ 267.8 Total accounts receivable, net – past due greater than 90 days (1) $ 7.5 $ 8.4 Past due greater than 90 days – collection risk mitigated by regulatory mechanisms (1) 93.7 % 95.5 % |
Rollforward of the allowances for credit losses | A rollforward of the allowance for credit losses is included below: Three Months Ended September 30 (in millions) 2023 2022 Balance at July 1 $ 10.6 $ 10.8 Provision for credit losses 1.9 1.6 Provision for credit losses deferred for future recovery or refund (0.3) (1.2) Write-offs charged against the allowance (3.3) (3.0) Recoveries of amounts previously written off 0.7 1.4 Balance at September 30 $ 9.6 $ 9.6 Nine Months Ended September 30 (in millions) 2023 2022 Balance at January 1 $ 11.7 $ 11.1 Provision for credit losses 3.4 5.6 Provision for credit losses deferred for future recovery or refund 0.2 (1.8) Write-offs charged against the allowance (9.7) (9.3) Recoveries of amounts previously written off 4.0 4.0 Balance at September 30 $ 9.6 $ 9.6 There was a $2.1 million decrease in the allowance for credit losses at September 30, 2023, compared to January 1, 2023. The decrease was driven by customer write-offs related to the end of the winter moratorium. After a customer is disconnected for a period of time without payment on their account, we will write off that customer balance. In addition, lower energy costs driven by lower natural gas prices contributed to a reduction in past due accounts receivable balances and a related decrease in the allowance for credit losses. There was a $1.5 million decrease in the allowance for credit losses at September 30, 2022, compared to January 1, 2022. The decrease was driven by customer write-offs related to collection practices returning to pre-pandemic levels in 2021, including the restoration of our ability to disconnect customers. Partially offsetting the decrease in the allowance for credit losses, we believe that the high energy costs that customers experienced during this time, which were driven by high natural gas prices, contributed to higher past due accounts receivable balances and a related increase in the allowance for credit losses. |
REGULATORY ASSETS AND LIABILI_2
REGULATORY ASSETS AND LIABILITIES (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Regulatory Assets and Liabilities Disclosure [Abstract] | |
Schedule of regulatory assets | (in millions) September 30, 2023 December 31, 2022 Regulatory assets Environmental remediation costs $ 114.9 $ 118.5 Income tax related items 58.0 61.5 Pension and OPEB costs 47.9 48.6 Plant retirement related items 39.7 43.1 Asset retirement obligations 18.3 15.6 Derivatives 14.2 22.5 Bluewater (1) 11.1 6.8 ReACT™ 11.0 13.0 Energy efficiency programs 7.1 13.4 Uncollectible expense 6.6 5.6 Other, net 19.3 16.9 Total regulatory assets $ 348.1 $ 365.5 (1) Primarily related to costs associated with our long-term service agreement with Bluewater for natural gas storage services. The PSCW has approved escrow accounting for these costs. As a result, we defer as a regulatory asset or liability the difference between actual storage costs and those included in rates until recovery or refund is authorized in a future rate proceeding. |
Schedule of regulatory liabilities | (in millions) September 30, 2023 December 31, 2022 Regulatory liabilities Income tax related items $ 334.4 $ 343.7 Removal costs 189.2 186.5 Pension and OPEB benefits 92.5 90.1 Energy costs refundable through rate adjustments 37.0 9.9 Derivatives 5.2 7.9 Other, net 29.2 22.1 Total regulatory liabilities $ 687.5 $ 660.2 Balance sheet presentation Amounts refundable to customers $ 17.6 $ 9.9 Regulatory liabilities 669.9 650.3 Total regulatory liabilities $ 687.5 $ 660.2 |
SHORT-TERM DEBT AND LINES OF _2
SHORT-TERM DEBT AND LINES OF CREDIT (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Short-Term Debt [Abstract] | |
Schedule of short-term borrowings and weighted-average interest rates | The following table shows our short-term borrowings and their corresponding weighted-average interest rates: (in millions, except percentages) September 30, 2023 December 31, 2022 Commercial paper Amount outstanding $ 131.0 $ 194.9 Weighted-average interest rate on amounts outstanding 5.38 % 4.60 % |
Schedule of revolving credit facility and remaining available capacity | The information in the table below relates to our revolving credit facility used to support our commercial paper borrowing program, including available capacity under this facility: (in millions) Maturity September 30, 2023 Revolving credit facility September 2026 $ 400.0 Less: Letters of credit issued inside credit facility $ 1.3 Commercial paper outstanding 131.0 Available capacity under existing credit facility $ 267.7 |
LEASES (Tables)
LEASES (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Leases [Abstract] | |
Schedule of future minimum lease payments for finance leases | Future minimum lease payments and the corresponding present value of our net minimum lease payments under the finance leases for Darien as of September 30, 2023, were as follows: (in millions) Three months ended December 31, 2023 $ — 2024 0.1 2025 0.3 2026 0.3 2027 0.3 2028 0.4 Thereafter 26.3 Total minimum lease payments 27.7 Less: Interest (21.0) Present value of minimum lease payments 6.7 Less: Short-term lease liabilities — Long-term lease liabilities $ 6.7 |
MATERIALS, SUPPLIES, AND INVE_2
MATERIALS, SUPPLIES, AND INVENTORIES (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Inventory Disclosure [Abstract] | |
Schedule of inventory | Our inventories consisted of: (in millions) September 30, 2023 December 31, 2022 Materials and supplies $ 75.4 $ 59.3 Natural gas in storage 41.1 65.0 Fossil fuel 39.8 40.2 Total $ 156.3 $ 164.5 |
INCOME TAXES (Tables)
INCOME TAXES (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Income Tax Disclosure [Abstract] | |
Schedule of effective income tax rate reconciliation | The provision for income taxes differs from the amount of income tax determined by applying the applicable United States statutory federal income tax rate to income before income taxes as a result of the following: Three Months Ended September 30, 2023 Three Months Ended September 30, 2022 (in millions) Amount Effective Tax Rate Amount Effective Tax Rate Statutory federal income tax $ 22.6 21.0 % $ 16.8 21.0 % State income taxes net of federal tax benefit 6.8 6.3 % 5.1 6.3 % PTCs, net (3.4) (3.2) % — — % Federal excess deferred tax amortization (1.9) (1.8) % (1.3) (1.6) % Federal excess deferred tax amortization – Wisconsin unprotected (1.3) (1.2) % (0.9) (1.1) % ITCs (1.3) (1.2) % (0.7) (0.9) % Other, net (0.1) — % (0.1) (0.1) % Total income tax expense $ 21.4 19.9 % $ 18.9 23.6 % Nine Months Ended September 30, 2023 Nine Months Ended September 30, 2022 (in millions) Amount Effective Tax Rate Amount Effective Tax Rate Statutory federal income tax $ 56.1 21.0 % $ 53.5 21.0 % State income taxes net of federal tax benefit 16.8 6.3 % 16.1 6.3 % PTCs, net (11.0) (4.1) % — — % Federal excess deferred tax amortization (4.8) (1.8) % (4.2) (1.7) % Federal excess deferred tax amortization – Wisconsin unprotected (3.2) (1.2) % (3.1) (1.2) % ITCs (3.2) (1.2) % (2.2) (0.9) % Other, net (0.4) (0.2) % 0.4 0.2 % Total income tax expense $ 50.3 18.8 % $ 60.5 23.7 % |
FAIR VALUE MEASUREMENTS (Tables
FAIR VALUE MEASUREMENTS (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Fair Value Disclosures [Abstract] | |
Schedule of fair value of assets and liabilities measured on a recurring basis categorized by level within the fair value hierarchy | The following tables summarize our financial assets and liabilities that were accounted for at fair value on a recurring basis, categorized by level within the fair value hierarchy: September 30, 2023 (in millions) Level 1 Level 2 Level 3 Total Derivative assets Natural gas contracts $ 0.3 $ 0.6 $ — $ 0.9 FTRs — — 3.9 3.9 Coal contracts — 0.7 — 0.7 Total derivative assets $ 0.3 $ 1.3 $ 3.9 $ 5.5 Derivative liabilities Natural gas contracts $ 10.1 $ 0.2 $ — $ 10.3 Coal contracts — 0.6 — 0.6 Total derivative liabilities $ 10.1 $ 0.8 $ — $ 10.9 December 31, 2022 (in millions) Level 1 Level 2 Level 3 Total Derivative assets Natural gas contracts $ 1.2 $ 0.5 $ — $ 1.7 FTRs — — 4.1 4.1 Coal contracts — 1.8 — 1.8 Total derivative assets $ 1.2 $ 2.3 $ 4.1 $ 7.6 Derivative liabilities Natural gas contracts $ 14.5 $ 2.4 $ — $ 16.9 |
Reconciliation of changes in the fair value of items categorized as level 3 measurements | The following table summarizes the changes to derivatives classified as Level 3 in the fair value hierarchy: Three Months Ended September 30 Nine Months Ended September 30 (in millions) 2023 2022 2023 2022 Balance at the beginning of the period $ 5.7 $ 10.3 $ 4.1 $ 1.4 Purchases — 0.1 6.3 11.7 Settlements (1.8) (4.0) (6.5) (6.7) Balance at the end of the period $ 3.9 $ 6.4 $ 3.9 $ 6.4 |
Schedule of carrying value and fair value of financial instruments not recorded at fair value | The following table shows the financial instruments included on our balance sheets that were not recorded at fair value: September 30, 2023 December 31, 2022 (in millions) Carrying Amount Fair Value Carrying Amount Fair Value Long-term debt (1) $ 1,958.8 $ 1,512.6 $ 1,958.0 $ 1,607.2 (1) The carrying amount of long-term debt excludes finance lease obligations of $49.0 million and $41.9 million at September 30, 2023 and December 31, 2022, respectively. |
DERIVATIVE INSTRUMENTS (Tables)
DERIVATIVE INSTRUMENTS (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Schedule of derivative assets and liabilities | The following table shows our derivative assets and derivative liabilities. None of the derivatives shown below are designated as hedging instruments. September 30, 2023 December 31, 2022 (in millions) Derivative Assets Derivative Liabilities Derivative Assets Derivative Liabilities Current Natural gas contracts $ 0.9 $ 10.2 $ 1.7 $ 16.3 FTRs 3.9 — 4.1 — Coal contracts 0.6 0.4 1.4 — Total current 5.4 10.6 7.2 16.3 Long-term Natural gas contracts — 0.1 — 0.6 Coal contracts 0.1 0.2 0.4 — Total long-term 0.1 0.3 0.4 0.6 Total $ 5.5 $ 10.9 $ 7.6 $ 16.9 |
Schedule of estimated notional volumes and realized gains and losses | Our estimated notional sales volumes and realized gains and losses were as follows: Three Months Ended September 30, 2023 Three Months Ended September 30, 2022 (in millions) Volumes Gains (Losses) Volumes Gains Natural gas contracts 7.4 Dth $ (11.4) 5.4 Dth $ 16.6 FTRs 2.2 MWh 8.1 2.0 MWh 1.6 Total $ (3.3) $ 18.2 Nine Months Ended September 30, 2023 Nine Months Ended September 30, 2022 (in millions) Volumes Gains (Losses) Volumes Gains Natural gas contracts 29.0 Dth $ (40.2) 24.5 Dth $ 38.2 FTRs 6.4 MWh 10.8 6.0 MWh 2.3 Total $ (29.4) $ 40.5 |
Schedule of net derivative instruments | The following table shows derivative assets and derivative liabilities if derivative instruments by counterparty were presented net on our balance sheets: September 30, 2023 December 31, 2022 (in millions) Derivative Assets Derivative Liabilities Derivative Assets Derivative Liabilities Gross amount recognized on the balance sheet $ 5.5 $ 10.9 $ 7.6 $ 16.9 Gross amount not offset on the balance sheet (0.4) (10.3) (1) (1.4) (14.8) (2) Net amount $ 5.1 $ 0.6 $ 6.2 $ 2.1 (1) Includes cash collateral posted of $9.9 million. |
EMPLOYEE BENEFITS (Tables)
EMPLOYEE BENEFITS (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Retirement Benefits [Abstract] | |
Schedule of net benefit cost (credit) | The following tables show the components of net periodic benefit cost (credit) (including amounts capitalized to our balance sheets) for our benefit plans. Pension Benefits Three Months Ended September 30 Nine Months Ended September 30 (in millions) 2023 2022 2023 2022 Service cost $ 1.2 $ 2.3 $ 3.6 $ 6.8 Interest cost 7.5 5.7 22.6 17.0 Expected return on plan assets (12.8) (13.8) (38.5) (41.4) Amortization of net actuarial loss 4.3 4.3 13.0 13.0 Net periodic benefit cost (credit) $ 0.2 $ (1.5) $ 0.7 $ (4.6) OPEB Benefits Three Months Ended September 30 Nine Months Ended September 30 (in millions) 2023 2022 2023 2022 Service cost $ 0.6 $ 1.0 $ 2.0 $ 3.0 Interest cost 1.5 1.0 4.6 3.2 Expected return on plan assets (4.0) (5.2) (12.2) (15.7) Amortization of prior service credit (2.5) (2.5) (7.6) (7.6) Amortization of net actuarial (gain) loss 0.3 (0.6) 0.8 (1.9) Net periodic benefit credit $ (4.1) $ (6.3) $ (12.4) $ (19.0) |
SEGMENT INFORMATION (Tables)
SEGMENT INFORMATION (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Segment Reporting [Abstract] | |
Schedule of information related to reportable segments | The following tables show summarized financial information for the three and nine months ended September 30, 2023 and 2022, related to our reportable segments: (in millions) Utility Other Wisconsin Public Service Corporation Three months ended September 30, 2023 Operating revenues $ 411.6 $ — $ 411.6 Other operation and maintenance 107.2 — 107.2 Depreciation and amortization 57.5 — 57.5 Other income, net 10.7 0.5 11.2 Interest expense 22.3 — 22.3 Income tax expense 21.3 0.1 21.4 Net income 85.8 0.4 86.2 (in millions) Utility Other Wisconsin Public Service Corporation Three months ended September 30, 2022 Operating revenues $ 435.3 $ — $ 435.3 Other operation and maintenance 89.9 — 89.9 Depreciation and amortization 50.1 — 50.1 Other income, net 10.8 0.2 11.0 Interest expense 17.3 — 17.3 Income tax expense 18.8 0.1 18.9 Net income 61.1 0.1 61.2 (in millions) Utility Other Wisconsin Public Service Corporation Nine months ended September 30, 2023 Operating revenues $ 1,284.1 $ — $ 1,284.1 Other operation and maintenance 320.5 — 320.5 Depreciation and amortization 168.7 — 168.7 Other income, net 33.8 1.8 35.6 Interest expense 66.3 — 66.3 Income tax expense 49.9 0.4 50.3 Net income 215.2 1.4 216.6 (in millions) Utility Other Wisconsin Public Service Corporation Nine months ended September 30, 2022 Operating revenues $ 1,332.7 $ — $ 1,332.7 Other operation and maintenance 268.0 — 268.0 Depreciation and amortization 149.3 — 149.3 Other income, net 31.7 1.0 32.7 Interest expense 50.5 — 50.5 Income tax expense 60.2 0.3 60.5 Net income 193.7 0.7 194.4 |
COMMITMENTS AND CONTINGENCIES (
COMMITMENTS AND CONTINGENCIES (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Commitments and Contingencies Disclosure [Abstract] | |
Schedule of regulatory assets and reserves related to manufactured gas plant sites | We have established the following regulatory assets and reserves for manufactured gas plant sites: (in millions) September 30, 2023 December 31, 2022 Regulatory assets $ 114.9 $ 118.5 Reserves for future environmental remediation 78.5 88.6 |
SUPPLEMENTAL CASH FLOW INFORM_2
SUPPLEMENTAL CASH FLOW INFORMATION (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Supplemental Cash Flow Information [Abstract] | |
Schedule of supplemental cash flow information | Nine Months Ended September 30 (in millions) 2023 2022 Cash paid for interest, net of amount capitalized $ 49.8 $ 39.1 Cash paid for income taxes, net 8.3 20.7 Significant non-cash investing and financing transactions: Accounts payable related to construction costs 28.4 33.1 Payable for the transfer of assets from WE 2.4 — Liabilities accrued for software licensing agreement — 1.5 |
Reconciliation Of Cash And Restricted Cash | The following table reconciles the cash, cash equivalents, and restricted cash amounts reported within the balance sheets to the total of these amounts shown on the statements of cash flows: (in millions) September 30, 2023 December 31, 2022 Cash and cash equivalents $ 1.5 $ 0.5 Restricted cash included in other long-term assets — 38.0 Cash, cash equivalents, and restricted cash $ 1.5 $ 38.5 |
GENERAL INFORMATION - GENERAL (
GENERAL INFORMATION - GENERAL (Details) | Sep. 30, 2023 customer |
Electric | |
Product Information [Line Items] | |
Number Of Customers | 464,000 |
Natural gas | |
Product Information [Line Items] | |
Number Of Customers | 342,000 |
ACQUISITIONS - RED BARN (Detail
ACQUISITIONS - RED BARN (Details) - Red Barn Wind Park $ in Millions | 1 Months Ended |
Apr. 30, 2023 USD ($) MW | |
Asset Acquisition | |
Capacity of generation unit (in megawatts) | MW | 82 |
Acquisition purchase price | $ | $ 143.8 |
ACQUISITIONS - WHITEWATER (Deta
ACQUISITIONS - WHITEWATER (Details) - Whitewater Cogeneration Facility $ in Millions | 1 Months Ended | |
Jan. 31, 2023 USD ($) | Jan. 01, 2023 MW | |
Asset Acquisition | ||
Capacity of generation unit (in megawatts) | MW | 236.5 | |
Acquisition purchase price | $ | $ 38 | |
Ownership (as a percentage) | 50% |
OPERATING REVENUES - DISAGGREGA
OPERATING REVENUES - DISAGGREGATION OF OPERATING REVENUES FOR UTILITY SEGMENT (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Disaggregation of Operating Revenues | ||||
Total operating revenues | $ 411.6 | $ 435.3 | $ 1,284.1 | $ 1,332.7 |
Utility segment | ||||
Disaggregation of Operating Revenues | ||||
Total operating revenues | 411.6 | 435.3 | 1,284.1 | 1,332.7 |
Utility segment | Other operating revenues | ||||
Disaggregation of Operating Revenues | ||||
Other operating revenues | 0.6 | 0.6 | 1.9 | 3.5 |
Utility segment | Transferred over time | Revenues from contracts with customers | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | 411 | 434.7 | 1,282.2 | 1,329.2 |
Utility segment | Electric | Transferred over time | Revenues from contracts with customers | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | 370.1 | 373 | 1,009.9 | 1,016.3 |
Utility segment | Natural gas | Transferred over time | Revenues from contracts with customers | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | $ 40.9 | $ 61.7 | $ 272.3 | $ 312.9 |
OPERATING REVENUES - DISAGGRE_2
OPERATING REVENUES - DISAGGREGATION OF ELECTRIC UTILITY OPERATING REVENUES BY CUSTOMER CLASS (Details) - Revenues from contracts with customers - Utility segment - Transferred over time - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | $ 411 | $ 434.7 | $ 1,282.2 | $ 1,329.2 |
Electric | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | 370.1 | 373 | 1,009.9 | 1,016.3 |
Electric | Total retail | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | 342.5 | 329.4 | 927.8 | 906.5 |
Electric | Residential | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | 131.1 | 122.6 | 365.5 | 351 |
Electric | Small commercial and industrial | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | 130.2 | 116.8 | 343.9 | 318.4 |
Electric | Large commercial and industrial customers | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | 79.1 | 87.8 | 211.9 | 230.5 |
Electric | Other | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | 2.1 | 2.2 | 6.5 | 6.6 |
Electric | Wholesale | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | 21.2 | 28.1 | 63.8 | 73.6 |
Electric | Resale | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | 4.4 | 9.1 | 14.7 | 21.2 |
Electric | Other utility | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | $ 2 | $ 6.4 | $ 3.6 | $ 15 |
OPERATING REVENUES - DISAGGRE_3
OPERATING REVENUES - DISAGGREGATION OF NATURAL GAS UTILITY OPERATING REVENUES BY CUSTOMER CLASS (Details) - Revenues from contracts with customers - Utility segment - Transferred over time - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | $ 411 | $ 434.7 | $ 1,282.2 | $ 1,329.2 |
Natural gas | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | 40.9 | 61.7 | 272.3 | 312.9 |
Natural gas | Total retail | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | 32 | 52.2 | 263.5 | 295 |
Natural gas | Residential | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | 21.2 | 29.6 | 167.9 | 178.6 |
Natural gas | Commercial and industrial | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | 10.8 | 22.6 | 95.6 | 116.4 |
Natural gas | Transportation | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | 4.4 | 3.9 | 16.2 | 14.6 |
Natural gas | Other utility | ||||
Disaggregation of Operating Revenues | ||||
Revenues from contracts with customers | $ 4.5 | $ 5.6 | $ (7.4) | $ 3.3 |
OPERATING REVENUES OTHER OPERAT
OPERATING REVENUES OTHER OPERATING REVENUES (Details) - Utility segment - Other operating revenues - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Disaggregation of Operating Revenues | ||||
Other operating revenues | $ 0.6 | $ 0.6 | $ 1.9 | $ 3.5 |
Late payment charges | ||||
Disaggregation of Operating Revenues | ||||
Other operating revenues | 0.8 | 0.8 | 3.1 | 3 |
Alternative revenues | ||||
Disaggregation of Operating Revenues | ||||
Other operating revenues | (0.3) | (0.3) | (1.5) | 0.2 |
Other | ||||
Disaggregation of Operating Revenues | ||||
Other operating revenues | $ 0.1 | $ 0.1 | $ 0.3 | $ 0.3 |
CREDIT LOSSES - GROSS RECEIVABL
CREDIT LOSSES - GROSS RECEIVABLES AND RELATED ALLOWANCES (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Jun. 30, 2023 | Dec. 31, 2022 | Sep. 30, 2022 | Jun. 30, 2022 | Dec. 31, 2021 |
Utility segment | ||||||
Accounts, Notes, Loans and Financing Receivable [Line Items] | ||||||
Accounts receivable and unbilled revenues | $ 212.3 | $ 279.5 | ||||
Allowance for credit losses | 9.6 | $ 10.6 | 11.7 | $ 9.6 | $ 10.8 | $ 11.1 |
Accounts receivable and unbilled revenues, net | 202.7 | 267.8 | ||||
Total accounts receivable, net - past due greater than 90 days | $ 7.5 | $ 8.4 | ||||
Past due greater than 90 days - collection risk mitigated by regulatory mechanisms | 93.70% | 95.50% | ||||
Amount of net accounts receivable with regulatory protections | $ 79.1 | |||||
Percent of net accounts receivable with regulatory protections | 39% | |||||
Other | ||||||
Accounts, Notes, Loans and Financing Receivable [Line Items] | ||||||
Accounts receivable and unbilled revenues | $ 0 | $ 0 |
CREDIT LOSSES - ROLLFORWARD OF
CREDIT LOSSES - ROLLFORWARD OF ALLOWANCES (Details) - Utility segment - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Accounts Receivable, Allowance for Credit Loss [Roll Forward] | ||||
Balance at beginning of period | $ 10.6 | $ 10.8 | $ 11.7 | $ 11.1 |
Provision for credit losses | 1.9 | 1.6 | 3.4 | 5.6 |
Write-offs charged against the allowance | (3.3) | (3) | (9.7) | (9.3) |
Recovery of amounts previously written off | 0.7 | 1.4 | 4 | 4 |
Balance at end of period | 9.6 | 9.6 | 9.6 | 9.6 |
Change in allowance for credit losses | 2.1 | 1.5 | ||
Uncollectible expense | ||||
Accounts Receivable, Allowance for Credit Loss [Roll Forward] | ||||
Provision for credit losses deferred for future recovery or refund | $ (0.3) | $ (1.2) | $ 0.2 | $ (1.8) |
REGULATORY ASSETS AND LIABILI_3
REGULATORY ASSETS AND LIABILITIES - REGULATORY ASSETS (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Regulatory assets | ||
Regulatory assets | $ 348.1 | $ 365.5 |
Environmental remediation costs | ||
Regulatory assets | ||
Regulatory assets | 114.9 | 118.5 |
Income tax related items | ||
Regulatory assets | ||
Regulatory assets | 58 | 61.5 |
Pension and OPEB costs | ||
Regulatory assets | ||
Regulatory assets | 47.9 | 48.6 |
Plant retirement related items | ||
Regulatory assets | ||
Regulatory assets | 39.7 | 43.1 |
Asset retirement obligations | ||
Regulatory assets | ||
Regulatory assets | 18.3 | 15.6 |
Derivatives | ||
Regulatory assets | ||
Regulatory assets | 14.2 | 22.5 |
Bluewater | ||
Regulatory assets | ||
Regulatory assets | 11.1 | 6.8 |
ReACT | ||
Regulatory assets | ||
Regulatory assets | 11 | 13 |
Energy efficiency programs | ||
Regulatory assets | ||
Regulatory assets | 7.1 | 13.4 |
Uncollectible expense | ||
Regulatory assets | ||
Regulatory assets | 6.6 | 5.6 |
Other, net | ||
Regulatory assets | ||
Regulatory assets | $ 19.3 | $ 16.9 |
REGULATORY ASSETS AND LIABILI_4
REGULATORY ASSETS AND LIABILITIES - REGULATORY LIABILITIES (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Regulatory liabilities | ||
Amounts refundable to customers | $ 17.6 | $ 9.9 |
Regulatory liabilities | 669.9 | 650.3 |
Total regulatory liabilities | 687.5 | 660.2 |
Income tax related items | ||
Regulatory liabilities | ||
Total regulatory liabilities | 334.4 | 343.7 |
Removal costs | ||
Regulatory liabilities | ||
Total regulatory liabilities | 189.2 | 186.5 |
Pension and OPEB benefits | ||
Regulatory liabilities | ||
Total regulatory liabilities | 92.5 | 90.1 |
Energy costs refundable through rate adjustments | ||
Regulatory liabilities | ||
Total regulatory liabilities | 37 | 9.9 |
Derivatives | ||
Regulatory liabilities | ||
Total regulatory liabilities | 5.2 | 7.9 |
Other, net | ||
Regulatory liabilities | ||
Total regulatory liabilities | $ 29.2 | $ 22.1 |
PROPERTY, PLANT, AND EQUIPMENT
PROPERTY, PLANT, AND EQUIPMENT (Details) $ in Millions | Sep. 30, 2023 USD ($) |
Columbia Energy Center Units 1 and 2 | |
Property, Plant and Equipment | |
Net book value of plant to be retired | $ 261.8 |
JOINTLY OWNED UTILITY FACILIT_2
JOINTLY OWNED UTILITY FACILITIES (Details) $ in Millions | Jul. 31, 2023 USD ($) generating_units MW | Apr. 30, 2023 MW | Jan. 31, 2023 MW |
Whitewater Cogeneration Facility | |||
Jointly owned utility facilities | |||
Capacity of generation unit (in megawatts) | 236.5 | ||
Ownership interest (as a percentage) | 50% | ||
Red Barn Wind Park | |||
Jointly owned utility facilities | |||
Ownership interest (as a percentage) | 90% | ||
Share of capacity (in megawatts) | 82 | ||
Weston RICE | |||
Jointly owned utility facilities | |||
Ownership interest (as a percentage) | 50% | ||
Share of capacity (in megawatts) | 64 | ||
Number of RICE units | generating_units | 7 | ||
Net property, plant, and equipment | $ | $ 88.3 |
SHORT-TERM DEBT AND LINES OF _3
SHORT-TERM DEBT AND LINES OF CREDIT - SHORT-TERM BORROWINGS (Details) - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2023 | Dec. 31, 2022 | |
Short-term borrowings | ||
Commercial paper outstanding | $ 131 | $ 194.9 |
Commercial paper | ||
Short-term borrowings | ||
Commercial paper outstanding | $ 131 | $ 194.9 |
Weighted-average interest rate on amounts outstanding | 5.38% | 4.60% |
Average amount outstanding during the period | $ 146.7 | |
Weighted-average interest rate during the period | 5.09% |
SHORT-TERM DEBT AND LINES OF _4
SHORT-TERM DEBT AND LINES OF CREDIT - REVOLVING CREDIT FACILITIES (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Revolving credit facility | ||
Commercial paper outstanding | $ 131 | $ 194.9 |
Available capacity under existing credit facility | 267.7 | |
Revolving credit facility maturing September 2026 | ||
Revolving credit facility | ||
Revolving credit facility | 400 | |
Letter of credit | ||
Revolving credit facility | ||
Letters of credit issued inside credit facility | 1.3 | |
Commercial paper | ||
Revolving credit facility | ||
Commercial paper outstanding | $ 131 | $ 194.9 |
LEASES - LAND LEASES - UTILITY
LEASES - LAND LEASES - UTILITY SOLAR GENERATION (Details) - Darien Solar Park $ in Millions | Sep. 30, 2023 USD ($) |
Leases | |
Ownership interest (as a percentage) | 15% |
Lease initial term | 25 years |
Renewal term | 25 years |
Finance lease obligations | $ 6.7 |
Finance lease right of use asset | $ 6.5 |
Weighted average discount rate | 5.96% |
LEASES - FUTURE MINIMUM LEASE P
LEASES - FUTURE MINIMUM LEASE PAYMENTS (Details) - Darien Solar Park $ in Millions | Sep. 30, 2023 USD ($) |
Finance leases | |
Three months ended December 31, 2023 | $ 0 |
2024 | 0.1 |
2025 | 0.3 |
2026 | 0.3 |
2027 | 0.3 |
2028 | 0.4 |
Thereafter | 26.3 |
Total minimum lease payments | 27.7 |
Less: Interest | (21) |
Present value of minimum lease payments | 6.7 |
Less: Short-term lease liabilities | 0 |
Long-term lease liabilities | $ 6.7 |
MATERIALS, SUPPLIES, AND INVE_3
MATERIALS, SUPPLIES, AND INVENTORIES (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Inventory Disclosure [Abstract] | ||
Materials and supplies | $ 75.4 | $ 59.3 |
Natural gas in storage | 41.1 | 65 |
Fossil fuel | 39.8 | 40.2 |
Total | $ 156.3 | $ 164.5 |
INCOME TAXES (Details)
INCOME TAXES (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Effective Income Tax Rate Reconciliation, Amount | ||||
Statutory federal income tax, amount | $ 22.6 | $ 16.8 | $ 56.1 | $ 53.5 |
State income taxes net of federal tax benefit,amount | 6.8 | 5.1 | 16.8 | 16.1 |
PTCs, net, amount | (3.4) | 0 | (11) | 0 |
Federal excess deferred tax amortization, amount | (1.9) | (1.3) | (4.8) | (4.2) |
Federal excess deferred tax amortization - Wisconsin unprotected, amount | (1.3) | (0.9) | (3.2) | (3.1) |
ITCs, amount | (1.3) | (0.7) | (3.2) | (2.2) |
Other, net, amount | (0.1) | (0.1) | (0.4) | 0.4 |
Total income tax expense, amount | $ 21.4 | $ 18.9 | $ 50.3 | $ 60.5 |
Effective Income Tax Rate Reconciliation, Percent | ||||
Statutory federal income tax, percent | 21% | 21% | 21% | 21% |
State income taxes net of federal tax benefit, percent | 6.30% | 6.30% | 6.30% | 6.30% |
PTCs, net, percent | (3.20%) | 0% | (4.10%) | 0% |
Federal excess deferred tax amortization, percent | (1.80%) | (1.60%) | (1.80%) | (1.70%) |
Federal excess deferred tax amortization - WI Unprotected, percent | (1.20%) | (1.10%) | (1.20%) | (1.20%) |
ITCs, percent | (1.20%) | (0.90%) | (1.20%) | (0.90%) |
Other, net, percent | 0% | (0.10%) | (0.20%) | 0.20% |
Total income tax expense, percent | 19.90% | 23.60% | 18.80% | 23.70% |
FAIR VALUE MEASUREMENTS - ASSET
FAIR VALUE MEASUREMENTS - ASSETS AND LIABILITIES MEASURED ON A RECURRING BASIS (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Assets | ||
Derivative assets | $ 5.5 | $ 7.6 |
Liabilities | ||
Derivative liabilities | 10.9 | 16.9 |
Fair value measurements on a recurring basis | ||
Assets | ||
Derivative assets | 5.5 | 7.6 |
Liabilities | ||
Derivative liabilities | 10.9 | |
Fair value measurements on a recurring basis | Level 1 | ||
Assets | ||
Derivative assets | 0.3 | 1.2 |
Liabilities | ||
Derivative liabilities | 10.1 | |
Fair value measurements on a recurring basis | Level 2 | ||
Assets | ||
Derivative assets | 1.3 | 2.3 |
Liabilities | ||
Derivative liabilities | 0.8 | |
Fair value measurements on a recurring basis | Level 3 | ||
Assets | ||
Derivative assets | 3.9 | 4.1 |
Liabilities | ||
Derivative liabilities | 0 | |
Fair value measurements on a recurring basis | Natural gas contracts | ||
Assets | ||
Derivative assets | 0.9 | 1.7 |
Liabilities | ||
Derivative liabilities | 10.3 | 16.9 |
Fair value measurements on a recurring basis | Natural gas contracts | Level 1 | ||
Assets | ||
Derivative assets | 0.3 | 1.2 |
Liabilities | ||
Derivative liabilities | 10.1 | 14.5 |
Fair value measurements on a recurring basis | Natural gas contracts | Level 2 | ||
Assets | ||
Derivative assets | 0.6 | 0.5 |
Liabilities | ||
Derivative liabilities | 0.2 | 2.4 |
Fair value measurements on a recurring basis | Natural gas contracts | Level 3 | ||
Assets | ||
Derivative assets | 0 | 0 |
Liabilities | ||
Derivative liabilities | 0 | 0 |
Fair value measurements on a recurring basis | FTRs | ||
Assets | ||
Derivative assets | 3.9 | 4.1 |
Fair value measurements on a recurring basis | FTRs | Level 1 | ||
Assets | ||
Derivative assets | 0 | 0 |
Fair value measurements on a recurring basis | FTRs | Level 2 | ||
Assets | ||
Derivative assets | 0 | 0 |
Fair value measurements on a recurring basis | FTRs | Level 3 | ||
Assets | ||
Derivative assets | 3.9 | 4.1 |
Fair value measurements on a recurring basis | Coal contracts | ||
Assets | ||
Derivative assets | 0.7 | 1.8 |
Liabilities | ||
Derivative liabilities | 0.6 | |
Fair value measurements on a recurring basis | Coal contracts | Level 1 | ||
Assets | ||
Derivative assets | 0 | 0 |
Liabilities | ||
Derivative liabilities | 0 | |
Fair value measurements on a recurring basis | Coal contracts | Level 2 | ||
Assets | ||
Derivative assets | 0.7 | 1.8 |
Liabilities | ||
Derivative liabilities | 0.6 | |
Fair value measurements on a recurring basis | Coal contracts | Level 3 | ||
Assets | ||
Derivative assets | 0 | $ 0 |
Liabilities | ||
Derivative liabilities | $ 0 |
FAIR VALUE MEASUREMENTS - LEVEL
FAIR VALUE MEASUREMENTS - LEVEL 3 RECONCILIATION (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Level 3 rollforward | ||||
Balance at the beginning of the period | $ 5.7 | $ 10.3 | $ 4.1 | $ 1.4 |
Purchases | 0 | 0.1 | 6.3 | 11.7 |
Settlements | (1.8) | (4) | (6.5) | (6.7) |
Balance at the end of the period | $ 3.9 | $ 6.4 | $ 3.9 | $ 6.4 |
FAIR VALUE MEASUREMENTS - FINAN
FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Carrying amount | ||
Financial instruments | ||
Long-term debt | $ 1,958.8 | $ 1,958 |
Finance lease obligations | 49 | 41.9 |
Fair value | ||
Financial instruments | ||
Long-term debt | $ 1,512.6 | $ 1,607.2 |
DERIVATIVE INSTRUMENTS - DERIVA
DERIVATIVE INSTRUMENTS - DERIVATIVE ASSETS AND LIABILITIES (Details) $ in Millions | Sep. 30, 2023 USD ($) Instruments | Dec. 31, 2022 USD ($) Instruments |
Derivative assets | ||
Current derivative assets | $ 5.4 | $ 7.2 |
Long-term derivative assets | 0.1 | 0.4 |
Total derivative assets | $ 5.5 | $ 7.6 |
Current derivative assets balance sheet location | Other | Other |
Long-term derivative assets balance sheet location | Other | Other |
Derivative liabilities | ||
Current derivative liabilities | $ 10.6 | $ 16.3 |
Long-term derivative liabilities | 0.3 | 0.6 |
Derivative liabilities | $ 10.9 | $ 16.9 |
Current derivative liability balance sheet location | Other | Other |
Long-term derivative liabilities balance sheet location | Other | Other |
Natural gas contracts | ||
Derivative assets | ||
Current derivative assets | $ 0.9 | $ 1.7 |
Long-term derivative assets | 0 | 0 |
Derivative liabilities | ||
Current derivative liabilities | 10.2 | 16.3 |
Long-term derivative liabilities | 0.1 | 0.6 |
FTRs | ||
Derivative assets | ||
Current derivative assets | 3.9 | 4.1 |
Derivative liabilities | ||
Current derivative liabilities | 0 | 0 |
Coal contracts | ||
Derivative assets | ||
Current derivative assets | 0.6 | 1.4 |
Long-term derivative assets | 0.1 | 0.4 |
Derivative liabilities | ||
Current derivative liabilities | 0.4 | 0 |
Long-term derivative liabilities | $ 0.2 | $ 0 |
Derivatives designated as hedging instruments | ||
Derivative instruments | ||
Number of derivative instruments | Instruments | 0 | 0 |
DERIVATIVE INSTRUMENTS - GAINS
DERIVATIVE INSTRUMENTS - GAINS (LOSSES) AND NOTIONAL VOLUMES (Details) MWh in Millions, MMBTU in Millions, $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 USD ($) MWh MMBTU | Sep. 30, 2022 USD ($) MMBTU MWh | Sep. 30, 2023 USD ($) MMBTU MWh | Sep. 30, 2022 USD ($) MMBTU MWh | |
Realized gains and losses | ||||
Realized gains and losses on derivatives income statement location | Cost of sales | Cost of sales | Cost of sales | Cost of sales |
Gains (losses) | $ (3.3) | $ 18.2 | $ (29.4) | $ 40.5 |
Natural gas contracts | ||||
Realized gains and losses | ||||
Gains (losses) | $ (11.4) | $ 16.6 | $ (40.2) | $ 38.2 |
Notional sales volumes | ||||
Notional sales volumes | MMBTU | 7.4 | 5.4 | 29 | 24.5 |
FTRs | ||||
Realized gains and losses | ||||
Gains (losses) | $ 8.1 | $ 1.6 | $ 10.8 | $ 2.3 |
Notional sales volumes | ||||
Notional sales volumes | MWh | 2.2 | 2 | 6.4 | 6 |
DERIVATIVE INSTRUMENTS - BALANC
DERIVATIVE INSTRUMENTS - BALANCE SHEET OFFSETTING (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Cash collateral | ||
Cash collateral posted | $ 21.8 | $ 26.6 |
Offsetting derivative assets | ||
Gross amount recognized on the balance sheet | 5.5 | 7.6 |
Gross amount not offset on the balance sheet | (0.4) | (1.4) |
Net amount | 5.1 | 6.2 |
Offsetting derivative liabilities | ||
Gross amount recognized on balance sheet | 10.9 | 16.9 |
Gross amount not offset on balance sheet | (10.3) | (14.8) |
Net amount | 0.6 | 2.1 |
Cash collateral posted | $ 9.9 | $ 13.4 |
GUARANTEES (Details)
GUARANTEES (Details) $ in Millions | Sep. 30, 2023 USD ($) |
Standby letters of credit | |
Guarantees | |
Guarantees with expiration over 3 years | $ 20.6 |
EMPLOYEE BENEFITS-COSTS AND CON
EMPLOYEE BENEFITS-COSTS AND CONTRIBUTIONS (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | Dec. 31, 2022 | |
Components of net periodic benefit cost (credit) | |||||
Regulatory assets | $ 348.1 | $ 348.1 | $ 365.5 | ||
Pension Benefits | |||||
Components of net periodic benefit cost (credit) | |||||
Service cost | 1.2 | $ 2.3 | 3.6 | $ 6.8 | |
Interest cost | 7.5 | 5.7 | 22.6 | 17 | |
Expected return on plan assets | (12.8) | (13.8) | (38.5) | (41.4) | |
Amortization of net actuarial (gain) loss | 4.3 | 4.3 | 13 | 13 | |
Net periodic benefit (credit) cost | 0.2 | (1.5) | 0.7 | (4.6) | |
Contributions and payments related to pension and OPEB plans | 0.5 | ||||
Estimated future employer contributions for the remainder of the year | 0.1 | 0.1 | |||
Pension Benefits | Pension and Other Postretirement Plans Cost | |||||
Components of net periodic benefit cost (credit) | |||||
Regulatory assets | 5.1 | 5.1 | |||
Other Postretirement Benefits | |||||
Components of net periodic benefit cost (credit) | |||||
Service cost | 0.6 | 1 | 2 | 3 | |
Interest cost | 1.5 | 1 | 4.6 | 3.2 | |
Expected return on plan assets | (4) | (5.2) | (12.2) | (15.7) | |
Amortization of prior service credit | (2.5) | (2.5) | (7.6) | (7.6) | |
Amortization of net actuarial (gain) loss | 0.3 | (0.6) | 0.8 | (1.9) | |
Net periodic benefit (credit) cost | (4.1) | $ (6.3) | (12.4) | $ (19) | |
Contributions and payments related to pension and OPEB plans | 0.7 | ||||
Estimated future employer contributions for the remainder of the year | 0.2 | 0.2 | |||
Other Postretirement Benefits | Pension and Other Postretirement Plans Cost | |||||
Components of net periodic benefit cost (credit) | |||||
Regulatory assets | $ 5.1 | $ 5.1 |
GOODWILL AND INTANGIBLE ASSETS
GOODWILL AND INTANGIBLE ASSETS (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |
Sep. 30, 2023 | Sep. 30, 2023 | Dec. 31, 2022 | |
Goodwill and Intangible Assets Disclosure [Abstract] | |||
Changes to the carrying amount of goodwill | $ 0 | ||
Accumulated impairment loss | $ 0 | 0 | |
Goodwill impairment loss | 0 | ||
Indefinite-Lived Intangible Assets | |||
Indefinite-lived intangible assets | 5.3 | 5.3 | $ 3.8 |
Spectrum frequencies | |||
Indefinite-Lived Intangible Assets | |||
Indefinite-lived intangible assets | $ 1.5 | $ 1.5 |
SEGMENT INFORMATION (Details)
SEGMENT INFORMATION (Details) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 USD ($) | Sep. 30, 2022 USD ($) | Sep. 30, 2023 USD ($) segment | Sep. 30, 2022 USD ($) | |
Segment Reporting [Abstract] | ||||
Number of reportable segments | segment | 2 | |||
Segment information | ||||
Operating revenues | $ 411.6 | $ 435.3 | $ 1,284.1 | $ 1,332.7 |
Other operation and maintenance | 107.2 | 89.9 | 320.5 | 268 |
Depreciation and amortization | 57.5 | 50.1 | 168.7 | 149.3 |
Other income, net | 11.2 | 11 | 35.6 | 32.7 |
Interest expense | 22.3 | 17.3 | 66.3 | 50.5 |
Income tax expense | 21.4 | 18.9 | 50.3 | 60.5 |
Net income | 86.2 | 61.2 | 216.6 | 194.4 |
Utility | ||||
Segment information | ||||
Operating revenues | 411.6 | 435.3 | 1,284.1 | 1,332.7 |
Other operation and maintenance | 107.2 | 89.9 | 320.5 | 268 |
Depreciation and amortization | 57.5 | 50.1 | 168.7 | 149.3 |
Other income, net | 10.7 | 10.8 | 33.8 | 31.7 |
Interest expense | 22.3 | 17.3 | 66.3 | 50.5 |
Income tax expense | 21.3 | 18.8 | 49.9 | 60.2 |
Net income | 85.8 | 61.1 | 215.2 | 193.7 |
Other | ||||
Segment information | ||||
Operating revenues | 0 | 0 | 0 | 0 |
Other operation and maintenance | 0 | 0 | 0 | 0 |
Depreciation and amortization | 0 | 0 | 0 | 0 |
Other income, net | 0.5 | 0.2 | 1.8 | 1 |
Interest expense | 0 | 0 | 0 | 0 |
Income tax expense | 0.1 | 0.1 | 0.4 | 0.3 |
Net income | $ 0.4 | $ 0.1 | $ 1.4 | $ 0.7 |
COMMITMENTS AND CONTINGENCIES -
COMMITMENTS AND CONTINGENCIES - UNCONDITIONAL PURCHASE OBLIGATIONS (Details) $ in Billions | Sep. 30, 2023 USD ($) |
Minimum future commitments for purchase obligations | |
Purchase obligations | $ 1 |
COMMITMENTS AND CONTINGENCIES_2
COMMITMENTS AND CONTINGENCIES - ENVIRONMENTAL MATTERS (Details) $ in Millions | 1 Months Ended | 9 Months Ended | ||||||
Aug. 31, 2023 | May 31, 2023 performance_obligations MW | Apr. 30, 2023 MMBTU | Jan. 31, 2023 micrograms | Dec. 31, 2020 micrograms performance_obligations | Sep. 30, 2023 USD ($) MW | Jun. 30, 2023 USD ($) | Dec. 31, 2022 USD ($) | |
Manufactured gas plant remediation | ||||||||
Regulatory assets | $ | $ 348.1 | $ 365.5 | ||||||
Environmental remediation costs | ||||||||
Manufactured gas plant remediation | ||||||||
Regulatory assets | $ | $ 114.9 | 118.5 | ||||||
Cross State Air Pollution Rule - Good Neighbor Plan | Electric | Maximum | ||||||||
Air quality | ||||||||
RICE unit megawatts | MW | 25 | |||||||
Mercury and Air Toxics Standards | Electric | ||||||||
Air quality | ||||||||
Current level of particulate matter in pounds per million british thermal unit | MMBTU | 0.03 | |||||||
EPA proposed lower limit for particulate matter | MMBTU | 0.01 | |||||||
Even lower level of particulate matter that the EPA is seeking opinions on | MMBTU | 0.006 | |||||||
National Ambient Air Quality Standards | Electric | ||||||||
Air quality | ||||||||
Number of revisions necessary to meet the 2012 standard for particulate matter | performance_obligations | 0 | |||||||
Current number of micrograms per cubic meter that particulate matter needs to be below | 12 | |||||||
Current number of micrograms per cubic meter under 24-hour standard that fine particulate matter needs to be below | 35 | |||||||
National Ambient Air Quality Standards | Electric | Maximum | ||||||||
Air quality | ||||||||
Period of time for EPA review of its new Integrated Review Plan for ozone | 5 years | |||||||
Proposed primary (health-based) annual standard | 10 | |||||||
The EPA is taking comments on this full range of micrograms per cubic meter | 11 | |||||||
New possible number of micrograms per cubic meter that particulate matter may be lowered to | 11 | |||||||
Lowest limit that will cause non-attainment | 10 | |||||||
National Ambient Air Quality Standards | Electric | Minimum | ||||||||
Air quality | ||||||||
Period of time for EPA review of its new Integrated Review Plan for ozone | 3 years | |||||||
Proposed primary (health-based) annual standard | 9 | |||||||
The EPA is taking comments on this full range of micrograms per cubic meter | 8 | |||||||
New possible number of micrograms per cubic meter that particulate matter may be lowered to | 10 | |||||||
Climate Change | Electric | ||||||||
Air quality | ||||||||
Number of applicable GHG performance standards for coal plants | performance_obligations | 0 | |||||||
Percent capacity factor that if combined cycle natural gas plants are above it causes the rule to be highly dependent on hydrogen or carbon capture | 50% | |||||||
Number of applicable limits that apply to simple cycle natural gas-fired combustion turbines that have less than a 20% capacity factor | performance_obligations | 0 | |||||||
Percent capacity factor for simple cycle natural gas fired combustion turbines that there are no applicable limits if the capacity factor is less than this | 20% | |||||||
Rules that are being proposed for natural gas-fired stationary combustion turbines | performance_obligations | 1 | |||||||
Number of subcategories of stationary combustion turbine unit annual capacity factors that the proposed rule will be broken up into | performance_obligations | 3 | |||||||
Capacity of coal-fired generation retired, in megawatts | MW | 400 | |||||||
Capacity of fossil-fueled generation to be retired by the end of 2026, in megawatts | MW | 1,500 | |||||||
Company goal for percent of carbon emission reduction below 2005 levels by the end of 2025 | 60% | |||||||
Company goal for percentage of carbon emission reduction below 2005 levels by the end of 2030 | 80% | |||||||
Climate Change | Electric | Maximum | ||||||||
Air quality | ||||||||
RICE unit megawatts | MW | 25 | |||||||
Steam Electric Effluent Limitation Guidelines | Electric | ||||||||
Water quality | ||||||||
BATW modifications completed at Weston Unit 3 to achieve required discharge limits | $ | $ 8 | |||||||
Manufactured Gas Plant Remediation | Natural gas | ||||||||
Manufactured gas plant remediation | ||||||||
Reserves for future environmental remediation | $ | $ 78.5 | 88.6 | ||||||
Manufactured Gas Plant Remediation | Natural gas | Environmental remediation costs | ||||||||
Manufactured gas plant remediation | ||||||||
Regulatory assets | $ | $ 114.9 | $ 118.5 |
SUPPLEMENTAL CASH FLOW INFORM_3
SUPPLEMENTAL CASH FLOW INFORMATION (Details) - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2023 | Sep. 30, 2022 | |
Supplemental Cash Flow Information [Abstract] | ||
Cash paid for interest, net of amount capitalized | $ 49.8 | $ 39.1 |
Cash paid for income taxes, net | 8.3 | 20.7 |
Significant non-cash investing and financing transactions: | ||
Accounts payable related to construction costs | 28.4 | 33.1 |
Payable for the transfer of assets from WE | 2.4 | 0 |
Liabilities accrued for software licensing agreement | $ 0 | $ 1.5 |
SUPPLEMENTAL CASH FLOW INFORM_4
SUPPLEMENTAL CASH FLOW INFORMATION - RECONCILIAATION OF CASH AND CASH EQUIVALENTS AND RESTRICTED CASH (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Jan. 01, 2023 | Dec. 31, 2022 | Sep. 30, 2022 | Dec. 31, 2021 |
Additional Cash Flow Elements and Supplemental Cash Flow Information [Abstract] | |||||
Cash and cash equivalents | $ 1.5 | $ 0.5 | |||
Restricted cash included in other long-term assets | 0 | 38 | |||
Cash, cash equivalents, and restricted cash | $ 1.5 | $ 38.5 | $ 0 | $ 2.4 | |
Whitewater Cogeneration Facility | |||||
Asset Acquisition | |||||
Ownership (as a percentage) | 50% |
REGULATORY ENVIRONMENT - 2024 L
REGULATORY ENVIRONMENT - 2024 LIMITED RATE CASE RE-OPENER (Details) - Public Service Commission of Wisconsin (PSCW) - Electric $ in Millions | 1 Months Ended |
May 31, 2023 USD ($) | |
Public Utilities, General Disclosures [Line Items] | |
Requested rate increase | $ 8.6 |
Requested rate increase (as a percent) | 0.50% |