EDGAR 10-K Filing

Company CIK: 107833
Filing Year: 2025
Filename: 107833_10-K_2025_0000107815-25-000107.json

---

ITEM 1. BUSINESS
ITEM 1. BUSINESS
A. INTRODUCTION
In this report, when we refer to "us," "we," "our," or "ours," we are referring to Wisconsin Public Service Corporation. The term "utility" refers to our regulated activities, while the term "non-utility" refers to our activities that are not regulated. References to "Notes" are to the Notes to Financial Statements included in this Annual Report on Form 10-K.
We are an indirect, wholly owned subsidiary of WEC Energy Group and were incorporated in the state of Wisconsin in 1883. We serve customers in northeastern and central Wisconsin. We conduct our business primarily through our utility reportable segment.
For more information about our utility operations, including financial and geographic information, see Note 20, Segment Information, and Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Results of Operations. For information about our business strategy, see Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Corporate Developments.
Available Information
Our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any amendments to those reports are made available on WEC Energy Group's website, www.wecenergygroup.com, free of charge, as soon as reasonably practicable after they are filed with or furnished to the SEC. The SEC maintains an Internet site that contains reports, proxy and information statements, and other information regarding issuers that file electronically with the SEC at www.sec.gov.
B. UTILITY SEGMENT
Electric Utility Operations
We generate and distribute electric energy to customers located in northeastern and central Wisconsin.
Operating Revenues
For information about our operating revenues disaggregated by customer class for the years ended December 31, 2024, 2023, and 2022, see Note 1(d), Operating Revenues, and Note 4, Operating Revenues.
Electric Sales
Our electric energy deliveries included supply and distribution sales to retail, wholesale, and resale customers. In 2024, retail revenues accounted for 92.1% of total electric operating revenues, wholesale revenues accounted for 4.6% of total electric operating revenues, and resale revenues accounted for 2.4% of total electric operating revenues. See Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Results of Operations - Utility Segment Contribution to Net Income for information on MWh sales by customer class.
We are authorized to provide retail electric service in designated territories in the state of Wisconsin, as established by indeterminate permits and boundary agreements with other utilities.
We provide wholesale electric service to various customers, including electric cooperatives, municipal joint action agencies, other investor-owned utilities, municipal utilities, and energy marketers.
The majority of our sales for resale are sold into an energy market operated by MISO at market rates based on the availability of our generation and market demand. Retail fuel costs are reduced by the amount that revenue exceeds the costs of sales derived from these opportunity sales.
2024 Form 10-K 4
Wisconsin Public Service Corporation
We buy and sell electric power by participating in the MISO Energy Markets. The cost of our individual generation offered into the MISO Energy Markets compared to our competitors affects how often our generating units are dispatched and whether we buy or sell power. For more information on the MISO Energy Markets, see D. Regulation.
Electric Sales Forecast
Our service territory experienced 0.3% lower weather-normalized retail electric sales in 2024, compared with 2023, mostly due to lower sales to large commercial and industrial customers. We currently forecast retail electric sales volumes to increase by 0.4% for 2025, assuming normal weather.
Customers
Year Ended December 31
(in thousands) 2024 2023 2022
Electric customers - end of year
Residential 413.9 409.7 405.6
Small commercial and industrial 56.2 55.7 55.4
Large commercial and industrial 0.2 0.2 0.2
Total electric customers - end of year 470.3 465.6 461.2
Electric Commercial and Industrial Retail Customers
We provide electric utility service to a diversified base of customers in industries such as metals and other manufacturing, paper, food manufacturing, utilities, and merchant wholesalers.
Electric Generation and Supply Mix
Our electric supply strategy is to provide our customers with energy from a diverse generation portfolio that is expected to balance a stable, reliable, and affordable supply of electricity with environmental stewardship. Through our participation in the MISO Energy Markets, we supply a significant amount of electricity to our customers from generation that we own. We supplement our internally generated power supply with long-term purchase power agreements and through spot purchases in the MISO Energy Markets. We also sell excess power supply into the MISO Energy Markets when it is economical, which reduces net fuel costs by offsetting costs of purchased power. All options, including owned generation resources and purchased power opportunities, are continually evaluated on a real time basis to select and dispatch the lowest-cost resources available to meet system load requirements.
The table below indicates our sources of electric energy supply as a percentage of sales for the three years ended December 31, as well as estimates for 2025:
Estimate (1)
Actual
2025 2024 2023 2022
Company-owned generation units:
Coal 36.1 % 34.9 % 29.7 % 34.2 %
Natural gas combined cycle 25.4 % 34.6 % 33.7 % 31.8 %
Natural gas/oil peaking units 3.1 % 5.3 % 5.7 % 3.1 %
Renewables (2)
11.1 % 10.5 % 9.8 % 8.7 %
Total company-owned generation units 75.7 % 85.3 % 78.9 % 77.8 %
Power purchase contracts - renewables (2)
4.1 % 4.8 % 5.0 % 4.9 %
Purchased power from MISO 20.2 % 9.9 % 16.1 % 17.3 %
Total purchased power 24.3 % 14.7 % 21.1 % 22.2 %
Total electric utility supply 100.0 % 100.0 % 100.0 % 100.0 %
(1) The values included in the estimate assume a natural gas price based on the December 2024 NYMEX.
(2) Includes hydroelectric, solar, and wind generation.
2024 Form 10-K 5
Wisconsin Public Service Corporation
Electric Generation Facilities
Our generation portfolio is a mix of energy resources having different operating characteristics and fuel sources designed to balance providing energy that is stable, reliable, and affordable with environmental stewardship. We own 2,719 MWs of generation capacity, including wholly owned and jointly owned facilities. Our facilities include natural gas-fired plants, coal-fired plants, and renewable generation. Certain of our natural gas-fired generation units have the ability to burn oil if natural gas is not available due to delivery constraints. For more information about our facilities, see Item 2. Properties.
Environmental Goals
WEC Energy Group has announced goals to achieve reductions in carbon emissions from its electric generation fleet, which includes us, by 60% by the end of 2025 and by 80% by the end of 2030, both from a 2005 baseline. As of the end of 2024, WEC Energy Group's electric generation fleet has achieved a 56% reduction in carbon emissions from the 2005 baseline. WEC Energy Group expects to achieve these goals by continuing to make 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 to be net carbon neutral by 2050.
As part of our path toward these goals, we plan to co-fire with natural gas at Weston Unit 4. By the end of 2030, we expect to use coal as a backup fuel only and to be in a position to eliminate coal as an energy source by the end of 2032.
Creating a Sustainable Future
WEC Energy Group's capital plan includes the retirement of older, fossil-fueled generation, to be replaced with zero-carbon-emitting renewables and reliable, efficient natural gas-fired generation. The retirements are intended to address compliance with the EPA Clean Air rules as well as contribute to meeting our goals to reduce CO2 emissions from our electric generation. When taken together, the retirements and new investments in renewables and reliable, efficient natural gas generation discussed in more detail below should better balance our supply with our demand, while helping to address compliance and maintaining reliable, affordable energy for our customers.
WEC Energy Group has already retired nearly 2,500 MWs of fossil-fueled generation since the beginning of 2018, which included the 2018 retirement of the Pulliam power plant and the jointly-owned Edgewater Unit 4 generating unit. See Note 6, Regulatory Assets and Liabilities, for more information related to these power plant retirements. WEC Energy Group expects to retire approximately 1,200 MWs of additional coal-fired generation by the end of 2031, which includes the planned retirement of jointly-owned Columbia Units 1 and 2 while investigating conversion of at least one unit to natural gas, and Weston Unit 3. See Note 7, Property, Plant, and Equipment, for more information.
See Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Corporate Developments for more information on WEC Energy Group's capital plan.
Also see Item 1A. Risk Factors - Risks Related to Legislation and Regulation - Our operations, capital expenditures, and financial results may be affected by the impact of greenhouse gas legislation, regulation, and emission reduction goals.
Renewable Generation
We meet a portion of our electric generation supply with various renewable energy resources, including wind, solar, and hydroelectric. This helps us work towards our goals of reducing carbon emissions while also maintaining compliance with renewable energy legislation. These renewable energy resources also help us maintain diversity in our generation portfolio, which effectively serves as a price hedge against future fuel costs, and will help mitigate the risk of potential unknown costs associated with any future carbon restrictions for electric generators.
2024 Form 10-K 6
Wisconsin Public Service Corporation
Wind
In September 2024, we, along with WE and an unaffiliated utility, filed a request with the PSCW to acquire and construct Badger Hollow Wind and to acquire Whitetail, two utility-scale wind-powered electric generating facilities. If approved, Badger Hollow Wind will be located in Iowa and Grant counties, Wisconsin, and Whitetail will be located in Grant County, Wisconsin. Once fully constructed, we will own 11 MWs of wind generation of Badger Hollow Wind and 7 MWs of wind generation of Whitetail. If approved, the construction of both of these projects is expected to be completed in 2027.
Solar and Battery Storage
In December 2024, the construction of the solar portion of Paris located in Kenosha County, Wisconsin was completed, and the facility became commercially operational. Paris is owned by us, along with WE and an unaffiliated utility. We own 30 MWs of solar generation and will own 17 MWs of battery storage of this project, with construction expected to be completed in 2025.
As part of our commitment to invest in additional zero-carbon generation, we have filed requests to acquire and construct 112 MWs of additional renewable generation and 30 MWs of battery storage, including the following:
•In October 2024, we, along with WE and an unaffiliated utility, filed a request with the PSCW to acquire and construct Good Oak and Gristmill, two utility-scale solar-powered electric generating facilities. If approved, both Good Oak and Gristmill will be located in Columbia County, Wisconsin. Once fully constructed, we will own 10 MWs of solar generation of Good Oak and 7 MWs of solar generation of Gristmill. If approved, the construction for both projects is expected to be completed in 2028.
•In September 2024, we, along with WE and an unaffiliated utility, filed a request with the PSCW to acquire Dawn Harvest, a utility-scale solar-powered electric generating facility with a battery energy storage system. If approved, the project will be located in Rock County, Wisconsin and once fully constructed, we will own 15 MWs of solar generation. If approved, the construction is expected to be completed in 2028.
•In September 2024, we, along with WE and an unaffiliated utility, filed a request with the PSCW to acquire Saratoga, a utility-scale solar-powered electric generating facility with a battery energy storage system, and Ursa, a utility-scale solar-powered electric generating facility. If approved, Saratoga will be located in Wood County, Wisconsin, and Ursa will be located in Columbia County, Wisconsin. Once fully constructed, we will own 15 MWs of solar generation and 5 MWs of battery storage of Saratoga and 20 MWs of solar generation of Ursa. If approved, the Ursa construction is expected to be completed in 2027, and the Saratoga construction is expected to be completed in 2028.
•In February 2024, we, along with WE and an unaffiliated utility, filed a request with the PSCW to acquire and construct High Noon, a utility-scale solar-powered electric generating facility with a battery energy storage system. If approved, the project will be located in Columbia County, Wisconsin and once fully constructed, we will own 45 MWs of solar generation and 25 MWs of battery storage of this project. If approved, the construction of the solar and battery storage is expected to be completed in 2027.
We have also received approvals from the PSCW to invest in 82 MWs of renewable generation and 37 MWs of battery storage currently under construction, including the following:
•In April 2023, we, along with WE and an unaffiliated utility, received PSCW approval to acquire Koshkonong, a utility-scale solar-powered electric generating facility with a battery energy storage system. The project will be located in Dane County, Wisconsin and once fully constructed, we will own 45 MWs of solar generation and 25 MWs of battery storage for this project. The construction of the solar portion and battery storage is expected to be completed in 2026 and 2027, respectively.
•In December 2022, we, along with WE and an unaffiliated utility, received PSCW approval to acquire and construct Darien, a utility-scale solar-powered electric generating facility with a battery energy storage system. The project will be located in Rock and Walworth counties, Wisconsin and once fully constructed, we will own 37 MWs of solar generation and 12 MWs of battery storage of this project. The construction of the solar portion and battery storage is expected to be completed in 2025 and 2026, respectively.
2024 Form 10-K 7
Wisconsin Public Service Corporation
Electric System Reliability
The PSCW requires us to maintain a planning reserve margin above our projected annual peak demand forecast to help ensure reliability of electric service to our customers. These planning reserve requirements are consistent with the MISO calculated planning reserve margin. In 2008, the PSCW established a 14.5% reserve margin requirement for long-term planning (planning years two through ten). For short-term planning (planning year one), the PSCW requires Wisconsin utilities to follow the planning reserve margin established by MISO. MISO implemented seasonal requirements effective June 1, 2023. The installed capacity reserve margins for the planning year June 1, 2024 through May 31, 2025 are as follows: 17.7% summer (June - August); 25.2% fall (September - November); 49.4% winter (December - February); and 40.8% spring (March - May). MISO's short-term reserve margin requirements experience year-to-year and season-to-season fluctuations, primarily due to changes in the generation resource mix and average forced outage rate of generation within the MISO footprint.
We believe that we have adequate capacity through company-owned generation units and power purchase contracts to meet the MISO calculated planning reserve margin during the current planning year. We also fully anticipate that we will have adequate capacity to meet the planning reserve margin requirements for the upcoming planning year.
Fuel and Purchased Power Costs
Our retail electric rates are established by the PSCW and include base amounts for fuel and purchased power costs. The electric fuel rules set by the PSCW generally allow us to defer, for subsequent rate recovery or refund, under- or over-collections of actual fuel and purchased power costs beyond a 2% price variance from the costs included in the rates charged to customers. For more information about the fuel rules, see D. Regulation.
Our average fuel and purchased power costs per MWh by fuel type, including delivery costs, were as follows for the years ended December 31:
2024 2023 2022
Coal $ 25.86 $ 26.09 $ 26.68
Natural gas combined cycle 19.75 31.88 38.98
Natural gas/oil peaking units 35.41 34.94 77.80
Purchased power 42.75 39.38 60.19
We purchase coal under long-term contracts, which helps with price stability. Coal and associated transportation services are exposed to volatility in pricing due to changing domestic and world-wide demand for coal and diesel fuel. To mitigate against this volatility risk, we have PSCW approval for a hedging program. This program allows us to hedge, over a 60-month period, up to 75% of our potential risks related to rail transportation fuel surcharge exposure. The results of this hedging program, when used, are reflected in the average costs of fuel and purchased power.
We purchase natural gas for our plants on the spot market from natural gas marketers, utilities, and producers, and we arrange for transportation of the natural gas to our plants. We have firm and interruptible transportation, as well as balancing and storage agreements, intended to support our plants' variable usage. We also have PSCW approval for a hedging program to mitigate against volatility related to natural gas price risk. This program allows us to hedge, over a 60-month period, up to 75% of our estimated natural gas use for electric generation. The results of this hedging program are reflected in the average costs of natural gas.
Coal Supply
We diversify the coal supply for our jointly-owned electric generating facilities by purchasing coal from several mines in Wyoming and Pennsylvania, as well as from various other states. For 2025, 87% of our total projected coal requirements of 1.8 million tons are contracted under fixed-price contracts. See Note 21, Commitments and Contingencies, for more information on amounts of coal purchases and coal deliveries under contract.
2024 Form 10-K 8
Wisconsin Public Service Corporation
The annual tonnage amounts contracted for the next three years are as follows:
(in thousands) Annual Tonnage
2025 1,552
2026 600
2027 -
Coal Deliveries
All of our coal requirements are expected to be shipped by unit trains that we own or lease under existing transportation agreements. The unit trains transport the coal for electric generating facilities from mines in Wyoming and Pennsylvania. Additional small volume agreements may also be used to supplement the normal coal supply for our facilities. For additional information concerning risks related to coal supply chain disruptions, see the risk factor below.
•Item 1A. Risk Factors - Risks Related to Economic and Market Volatility - We may not be able to obtain an adequate supply of coal, which could limit our ability to operate our coal-fired facilities.
Power Purchase Commitments
We enter into short- and long-term power purchase commitments to meet a portion of our anticipated electric energy supply needs. Excluding planning capacity purchases, our power purchase commitments with unaffiliated parties consist of 100 MWs per year for 2025 through 2029. To procure additional planning capacity, we purchase capacity from the MISO annual auction to ensure that we maintain our compliance with planning reserve requirements as established by the PSCW and MISO.
Seasonality
Our electric utility sales are impacted by seasonal factors and varying weather conditions. We sell more electricity during the summer months because of the residential cooling load. We continue to upgrade our electric distribution system, including substations, transformers, and lines, to meet the demand of our customers. In 2024, our generating plants performed as expected during the most demanding periods of the year, and all power purchase commitments under firm contract were received. During this period, we did not make any public appeals for conservation, and we did not interrupt or curtail service to non-firm customers who participate in load management programs. We did have economic interruption events; however, service to customers was not curtailed. Economic interruptions are declared during times in which the price of electricity in the regional market exceeds the cost of operating our peaking generation. During this time, customers taking service under these interruptible programs can choose to continue using electricity at a price based on wholesale market prices or to reduce their load.
Competition
We face competition from various entities and other forms of energy sources available to customers, including self-generation by customers and alternative energy sources. We compete with other utilities for sales to municipalities and cooperatives as well as with other utilities and marketers for wholesale electric business.
For more information on competition in our service territory, see Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Factors Affecting Results, Liquidity, and Capital Resources - Competitive Markets.
Natural Gas Utility Operations
We are authorized to provide retail natural gas distribution service in designated territories in the state of Wisconsin, as established by indeterminate permits and boundary agreements with other utilities. Our natural gas utility provides service to customers located in northeastern Wisconsin.
We provide service to residential and commercial and industrial customers. In addition, we offer natural gas transportation services to our customers that elect to purchase natural gas directly from a third-party supplier. Major industries served include paper, food manufacturing, governmental, education, and real estate. See Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Results of Operations - Utility Segment Contribution to Net Income for information on natural gas sales volumes by customer class.
2024 Form 10-K 9
Wisconsin Public Service Corporation
Operating Revenues
For information about our operating revenues disaggregated by customer class for the years ended December 31, 2024, 2023, and 2022, see Note 1(d), Operating Revenues, and Note 4, Operating Revenues.
Natural Gas Sales Forecast
Our service territory experienced slightly higher weather-normalized retail natural gas deliveries (excluding natural gas deliveries for electric generation) in 2024 as compared to 2023. We currently forecast retail natural gas delivery volumes to grow 2.2% in 2025, assuming normal weather.
Customers
Year Ended December 31
(in thousands) 2024 2023 2022
Customers - end of year
Residential 310.5 307.6 304.8
Commercial and industrial 35.3 35.2 34.9
Transportation 1.0 1.0 0.9
Total customers 346.8 343.8 340.6
Natural Gas Supply, Pipeline Capacity and Storage
We manage portfolios of natural gas supply contracts, storage services, and pipeline transportation services designed to meet varying customer use patterns. For more information on our natural gas utility supply and transportation contracts, see Note 21, Commitments and Contingencies.
Pipeline Capacity and Storage
We have long-term firm capacity contracts with interstate pipelines that access supply from a variety of natural gas producing areas. This strategy reflects management's belief that overall supply security is enhanced by geographic diversification of the supply portfolio.
Due to variations in natural gas usage in Wisconsin, we have also contracted for substantial underground storage capacity, primarily in Michigan. We have entered into a long-term service agreement for natural gas storage with a wholly owned subsidiary of Bluewater. Bluewater, a wholly owned subsidiary of WEC Energy Group, owns natural gas storage facilities in Michigan and provides approximately one-third of our current storage needs. We target storage inventory levels at approximately 40% of forecasted demand for November through March. Diversity of natural gas supply enables us to manage significant changes in demand and to optimize our overall natural gas supply and capacity costs. We generally inject natural gas into storage during the spring and summer months and withdraw it in the winter months.
We contract with interstate pipeline companies, as well as other service providers, to purchase firm transportation and storage services under varied-length long-term contracts. We believe that having diverse capacity and storage benefits our customers.
Combined with our storage capability, management believes that the volume of natural gas under contract is sufficient to meet our forecasted firm peak-day and seasonal demand. Our forecasted design peak-day throughput is 9.0 million therms for the 2024 through 2025 heating season. Our peak daily send-out during 2024 was 6.0 million therms on December 12, 2024. Peak or near-peak demand generally occurs only a few times each year. Natural gas pipeline capacity and storage and natural gas supplies under contract can be resold in secondary markets. The secondary markets facilitate utilization of capacity and supply during times when the contracted capacity and supply are in excess of utility demand. The proceeds from these transactions are passed through to customers, subject to our approved GCRM. For information on our GCRM, see Note 1(d), Operating Revenues.
2024 Form 10-K 10
Wisconsin Public Service Corporation
Natural Gas Supply
Our natural gas supply requirements are met through a combination of fixed-price purchases, index-priced purchases, storage, peak-shaving facilities, and natural gas supply call options. We contract for fixed-term firm natural gas supply each year to meet the demand of firm system sales customers. To supplement natural gas supply and manage risk, we purchase additional natural gas supply on the monthly and daily spot markets.
Hedging Natural Gas Supply Prices
As part of our hedging program, we further reduce our supply cost volatility through the use of a mix of financial instruments, such as NYMEX-based natural gas options and futures contracts. We have PSCW approval to hedge up to 60% of planned winter demand and up to 15% of planned summer demand. This approval allows us to pass 100% of the hedging costs (premiums, brokerage fees and losses) and proceeds (gains) to customers through our GCRM.
Seasonality
Since the majority of our customers use natural gas for heating, customer use is sensitive to weather and is generally higher during the winter months. Accordingly, we are subject to some variations in earnings and working capital throughout the year as a result of changes in weather.
Our working capital needs are met by cash generated from operations and debt (both long-term and short-term). The seasonality of natural gas revenues causes the timing of cash collections to be concentrated from January through June. A portion of our winter natural gas supply needs is typically purchased and stored from April through November. Also, planned capital spending on our natural gas distribution facilities is concentrated in April through November. Because of these timing differences, the cash flow from customers is typically supplemented with temporary increases in short-term borrowings (from external sources) during the late summer and fall. Short-term debt is typically reduced over the January through June period.
Competition
We face varying degrees of competition from other entities and other forms of energy available to consumers. Many large commercial and industrial customers have the ability to switch between natural gas and alternative fuels. Electrification initiatives or mandates are being considered or proposed by local and state governments. In addition, all of our customers have the opportunity to choose a natural gas supplier other than us. We offer natural gas transportation services for customers that elect to purchase natural gas directly from a third-party supplier. We continue to earn distribution revenues from these transportation customers for their use of our distribution system to transport natural gas to their facilities. As such, the loss of revenue associated with the cost of natural gas that our transportation customers purchase from third-party suppliers has little impact on our net income, as it is offset by an equal reduction to natural gas costs.
For more information on competition in our service territory, see Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Factors Affecting Results, Liquidity, and Capital Resources - Competitive Markets.
Environmental Goals
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 continuous operational improvements and equipment upgrades, as well as the use of RNG throughout its natural gas utility systems. In 2022, we received approval from the PSCW for an RNG pilot and in 2023, we began transporting the output of local dairy farms onto our natural gas distribution systems. The RNG supplied is expected to directly replace higher-emission methane from natural gas that would have entered our pipes. In addition, subject to regulatory approval, WEC Energy Group expects to procure RTCs.
C. OTHER SEGMENT
Our other segment includes our non-utility activities as well as equity earnings from our investment in WRPC. We own 50% of the stock of WRPC. WRPC owns two hydroelectric plants, and we are entitled to 50% of the total capacity from its plants.
2024 Form 10-K 11
Wisconsin Public Service Corporation
D. REGULATION
In addition to the specific regulations noted below, we are also subject to various other regulations, which primarily consist of regulations, where applicable, of the EPA, the WDNR, and the United States Army Corps of Engineers.
Rates
Our retail electric and natural gas rates are regulated by the PSCW, and the FERC regulates our wholesale electric rates. Decisions by these regulators can significantly impact our liquidity, financial condition, and results of operations. The following table compares our utility operating revenues by regulatory jurisdiction for each of the three years ended December 31:
2024 2023 2022
(in millions) Amount Percent Amount Percent Amount Percent
Electric
Wisconsin $ 1,154.2 92.8 % $ 1,211.2 92.3 % $ 1,189.0 90.2 %
FERC - Wholesale 90.2 7.2 % 100.9 7.7 % 129.4 9.8 %
Total 1,244.4 100.0 % 1,312.1 100.0 % 1,318.4 100.0 %
Natural Gas - Wisconsin 316.0 100.0 % 369.3 100.0 % 466.8 100.0 %
Total utility operating revenues $ 1,560.4 $ 1,681.4 $ 1,785.2
Retail Rates
The PSCW has general supervisory and regulatory powers over public utilities in its jurisdiction including, but not limited to, approval of retail utility rates and standards of service, security issuances, mergers, affiliate transactions, location and construction of electric generating units and natural gas facilities, and certain other additions and extensions to utility facilities.
Historically, retail rates approved by the PSCW have been designed to provide utilities the opportunity to generate revenues to recover all prudently-incurred costs, along with a return on investment sufficient to pay interest on debt and provide a reasonable ROE. Rates charged to customers vary according to customer class and rate jurisdiction. We are subject to an earnings sharing mechanism in which a portion of our earnings are required to be refunded to customers if we earn above our authorized ROE. See Note 23, Regulatory Environment, for more information on our earnings sharing mechanism. The table below reflects our approved ROE and capital structure during 2024.
Regulated Retail Rates Regulatory Commission Authorized ROE Average Common Equity Component
Electric and natural gas PSCW 9.80% 53.0%
In addition to amounts collected from customers through approved base rates, we have certain recovery mechanisms in place that allow us to recover or refund prudently incurred costs that differ from those approved in base rates.
Embedded within our electric rates is an amount to recover fuel and purchased power costs. The Wisconsin retail fuel rules require us to defer, for subsequent rate recovery or refund, any under-collection or over-collection of fuel and purchased power costs that are outside of our symmetrical fuel cost tolerance, which the PSCW typically sets at plus or minus 2% of our approved fuel and purchased power cost plan. Our deferred fuel and purchased power costs are subject to an excess revenues test. If our ROE in a given year exceeds the ROE authorized by the PSCW, the recovery of under-collected fuel and purchased power costs would be reduced by the amount by which our return exceeds the authorized amount.
Our natural gas utility operates under a GCRM as approved by the PSCW. Generally, the GCRM allows for a dollar-for-dollar recovery of prudently incurred natural gas costs.
See Note 1(d), Operating Revenues, for more information on the significant mechanisms we had in place during 2024 that allowed us to recover or refund changes in prudently incurred costs from rate case-approved amounts.
We file periodic requests with the PSCW for changes in retail rates. Our rate requests are based on forward looking test years, which reflect additions to infrastructure and changes in costs incurred or expected to be incurred. For information on our regulatory proceedings, see Note 23, Regulatory Environment. Orders from the PSCW can be viewed at https://psc.wi.gov/. The material and
2024 Form 10-K 12
Wisconsin Public Service Corporation
information contained on this website are not intended to be a part of, nor are they incorporated by reference into, this Annual Report on Form 10-K.
Wholesale Rates
The FERC regulates our wholesale sales of electric energy, capacity, and ancillary services. We have received market-based rate authority from the FERC. Market-based rate authority allows wholesale electric sales to be made in the MISO market and directly to third parties based on the negotiated market value of the transaction. We also make wholesale sales pursuant to cost-based formula rates. Cost-based formula rates provide for recovery of our costs and an approved rate of return. The predetermined formula is initially based on our expenses from the previous year, but is eventually trued up to reflect actual, current-year costs.
Electric Transmission, Capacity, and Energy Markets
In connection with its status as a FERC-approved RTO, MISO operates an energy and ancillary services market and manages the flow of high-voltage electricity across the transmission system in its region. MISO is responsible for monitoring and ensuring equal access to the electric transmission system in its footprint.
In MISO, transmission costs are allocated in accordance with the MISO tariff, which is reviewed and approved by the FERC. Base transmission costs are paid by load-serving entities located in the service territories of each MISO transmission owner. Costs for new regional transmission projects are allocated to load-serving entities throughout the MISO footprint, while the costs for new generation interconnections are allocated to the interconnection customer.
Within MISO, transmission congestion is monetized and included within an LMP that is established through the energy market. The LMP system includes the ability to hedge transmission congestion costs through ARRs and FTRs. ARRs are allocated to market participants by MISO, and FTRs are purchased through auctions. A new allocation and auction was completed for the period of June 1, 2024, through May 31, 2025. The resulting ARR allocation and the secured FTRs are expected to mitigate our transmission congestion risk for that period.
MISO has seasonal zonal resource adequacy requirements to ensure there is sufficient generation capacity to serve load within each zone and the MISO footprint. To meet this requirement, load-serving entities can own generation and demand response resources, acquire generation capacity through MISO's annual capacity auction, or acquire generation capacity through bilateral contracts. The zone in which our load resides, along with the MISO North region as a whole, has sufficient generation capacity resources to meet their respective planning reserve margins for the period between June 1, 2024 and May 31, 2025.
We manage our electric generation portfolio to minimize our exposure within MISO’s annual capacity auction. This includes managing the retirement of existing generation resources and the addition of new generation resources to maintain a diversified portfolio to help avoid a significant short position.
Other Electric Regulations
We are subject to the Federal Power Act and the corresponding regulations developed by certain federal agencies. Among other things, the Federal Power Act makes electric utility industry consolidation more feasible and authorizes the FERC to review proposed mergers and the acquisition of generation facilities. The FERC also oversees the Electric Reliability Organization, which establishes mandatory electric reliability standards and has the authority to levy monetary sanctions for failure to comply with these standards.
We are subject to Act 141 in Wisconsin which contains certain minimum requirements for renewable energy generation.
Other Natural Gas Regulations
Almost all of the natural gas we distribute is transported to our distribution systems by interstate pipelines. The pipelines' transportation and storage services are regulated by the FERC under the Natural Gas Act and the Natural Gas Policy Act of 1978. In addition, the PHMSA and the PSCW are responsible for monitoring and enforcing requirements governing our natural gas safety compliance programs for our pipelines under United States Department of Transportation regulations. These regulations include 49 CFR Part 191 (Transportation of Natural and Other Gas by Pipeline; Annual Reports, Incident Reports, and Safety-Related Condition Reports), 49 CFR Part 192 (Transportation of Natural and Other Gas by Pipeline: Minimum Federal Safety Standards), and 49 CFR Part 195 (Transportation of Hazardous Liquids by Pipeline).
2024 Form 10-K 13
Wisconsin Public Service Corporation
We also continue to monitor the progress of the PHMSA’s proposed rulemaking titled "Gas Pipeline Leak Detection and Repair," which could have a significant impact on us.
We are required to provide natural gas service and grant credit (with applicable deposit requirements) to customers within our service territory. We are generally not allowed to discontinue natural gas service during winter moratorium months to residential heating customers who do not pay their bills. Federal and certain state governments have programs that provide for a limited amount of funding for assistance to our low-income customers.
Compliance Costs
The regulations and oversight described above significantly influence our operating environment, and may cause us to incur compliance and other related costs and may affect our ability to recover these costs from our utility customers. Any anticipated capital expenditures for compliance with government regulations for the next three years are included in the estimated capital expenditures described in Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Liquidity and Capital Resources - Cash Requirements.
E. ENVIRONMENTAL COMPLIANCE
Our operations, especially as they relate to our coal-fired generating facilities, are subject to extensive environmental regulation by state and federal environmental agencies governing air and water quality, hazardous and solid waste management, environmental remediation, and management of natural resources. Costs associated with complying with these requirements are significant. Additional future environmental regulations or revisions to existing laws, including for example, additional regulation related to GHG emissions, coal combustion products, air emissions, water use, or wastewater discharges and other climate change issues, could significantly increase these environmental compliance costs.
Anticipated expenditures for environmental compliance and certain remediation issues for the next three years are included in the estimated capital expenditures described in Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Liquidity and Capital Resources - Cash Requirements. For a discussion of certain environmental matters affecting us, including rules and regulations relating to air quality, water quality, land quality, and climate change, see Note 21, Commitments and Contingencies.
F. HUMAN CAPITAL
We believe our employees are among our most important resources, so investing in human capital is critical to our success. We strive to attract, retain, and develop talented personnel and keep our employees safe, healthy, and engaged.
WEC Energy Group's Board of Directors retains collective responsibility for comprehensive risk oversight of WEC Energy Group and its subsidiaries, including critical areas that could impact our sustainability, such as human capital. Management regularly reports to WEC Energy Group's Board of Directors on human capital management topics, including corporate culture, succession planning, training and employee development, and safety and health. WEC Energy Group's Board of Directors delegates specified duties to its committees. In addition to its responsibilities relative to executive compensation, the Compensation Committee has oversight responsibility for reviewing organizational matters that could significantly impact us. The Compensation Committee reviews recruiting and development programs and priorities, receives updates on key talent, and assesses workforce composition across WEC Energy Group and its subsidiaries.
Workforce
As of December 31, 2024, we had 1,180 employees, including 850 that are represented under union agreements. We believe we have very good overall relations with our workforce. In order to attract and retain talent, we provide competitive wages and benefits to our employees based on their performance, role, location, and market data. Our compensation package also includes a 401(k) savings plan with an employer match, an annual incentive plan based on meeting company goals, healthcare and insurance benefits, vacation and paid time off days, as well as other benefits.
2024 Form 10-K 14
Wisconsin Public Service Corporation
Engagement
We are committed to ensuring a fair workplace and an engaged workforce. Our commitment is a core strategic competency and an integral part of our culture, with longstanding programs for individual development, reinforcement of our core values, and a recruitment strategy that is focused on building a deep talent pipeline to support our business needs. During 2024, we demonstrated this commitment through training and development of employees at all levels of the organization, our comprehensive merit review and succession planning processes, and a range of community partnerships. In addition, WEC Energy Group has a number of initiatives that promote workforce contributions and participation and ensure its companies, including us, are attractive employers for persons of all backgrounds. These initiatives include nine business resource groups (voluntary, employee-led groups organized around a particular shared background or interest), mentoring programs, and education and training for all employees in order to develop and support inclusive teams. We are committed to a workplace free from bias and harassment. We also support external leadership and educational programs that support, train, and promote individuals in the communities we serve.
Safety and Health
WEC Energy Group's Executive Safety Committee directs our safety and health strategy, works to ensure consistency across groups, and reinforces our ongoing safety commitment that we refer to as “Target Zero.” Under our Target Zero commitment, we have an ultimate goal of zero incidents, accidents, and injuries. Our corporate safety program provides a forum for addressing employee concerns, training employees and contractors on current safety standards, and recognizing those who demonstrate a safety focus. We monitor and set goals for days away, restricted or transferred metrics, and measurable leading indicators, which together raise awareness about employee safety and guide injury-prevention activities.
We also provide employees various benefits and resources designed to promote healthy living, both at work and at home. We encourage employees to receive preventive examinations and to proactively care for their health through free health screenings, wellness challenges, and other resources.
Development and Training
Employee training and development of both technical and leadership skills are integral aspects of our human capital strategy. We provide employees with a wide range of development opportunities, including online training, simulations, live classes, and mentoring to assist with their career advancement. These programs include safety and technical job skill training as well as soft-skill programs focused on relevant subjects, including communication and change management. Development of leadership skills remains a top priority and is specialized for all levels of employees. We have specific leadership programs for aspiring leaders and new supervisors, managers, and directors. This development of our employees is an integral part of our succession planning and provides continuity for our senior leadership.
2024 Form 10-K 15
Wisconsin Public Service Corporation

---

ITEM 1A. RISK FACTORS
ITEM 1A. RISK FACTORS
We are subject to a variety of risks, many of which are beyond our control, that may adversely affect our business, financial condition, and results of operations. You should carefully consider the following risk factors, as well as the other information included in this report and other documents filed by us with the SEC from time to time, when making an investment decision.
Risks Related to Legislation and Regulation
Our business is significantly impacted by governmental regulation and oversight.
We are subject to significant state, local, and federal governmental regulations, including regulations by the PSCW and the FERC. These regulations significantly influence our operating environment, may affect our ability to recover costs from utility customers, affect our ability to implement WEC Energy Group's corporate strategy, and cause us to incur substantial compliance and other costs. Changes in regulations, interpretations of regulations, or the imposition of new regulations could also significantly impact us, including requiring us to change our business operations. Many aspects of our operations are regulated and impacted by government regulation, including, but not limited to: the rates we charge our retail electric and natural gas customers; our authorized rate of return; construction and operation of electric generating facilities and electric and natural gas distribution systems, including the ability to recover such costs; decommissioning generating facilities, the ability to recover the related costs, and continuing to recover the return on the net book value of these facilities; wholesale power service practices; electric reliability requirements; participation in the interstate natural gas pipeline capacity market; standards of service; issuance of debt securities; short-term debt obligations; transactions with affiliates; and billing practices. Failure to comply with any applicable rules or regulations may lead to customer refunds, penalties, and other payments, which could materially and adversely affect our results of operations and financial condition.
The rates we are allowed to charge our customers for retail and wholesale services have the most significant impact on our financial condition, results of operations, and liquidity. Rate regulation provides us an opportunity to recover prudently incurred costs and earn a reasonable rate of return on invested capital. However, our ability to obtain rate adjustments in the future is dependent upon regulatory action, the outcome of which can be influenced by the level of opposition by intervening parties; potential rate impacts; increasing levels of regulatory review; and changes in the political, regulatory, or legislative environments. There is no assurance that our regulators will consider all of our costs to have been prudently incurred. In addition, our rate proceedings may not always result in rates that fully recover our costs or provide for a reasonable ROE. We defer certain costs and revenues as regulatory assets and liabilities for future recovery from or refund to customers, as authorized by our regulators. Future recovery of regulatory assets is not assured and is subject to review and approval by our regulators. If recovery of regulatory assets is not approved or is no longer deemed probable, these costs would be recognized in current period expense and could have a material adverse impact on our results of operations, cash flows, and financial condition.
Changes in the local and national political, regulatory, and economic environment have had, and may in the future have, an adverse effect on regulatory decisions, which could impair our ability to recover costs historically collected from customers. These decisions, which may come from any level of government, may cause us to cancel or delay current or planned projects, to reduce or delay other planned capital expenditures, or to pay for investments or otherwise incur costs that we may not be able to recover through rates or otherwise.
We believe we have obtained the necessary permits, approvals, authorizations, certificates, and licenses for our existing operations, have complied in all material respects with all of their associated terms, and that our business is conducted in accordance with applicable laws. These permits, approvals, authorizations, certificates, and licenses may be revoked or modified by the agencies that granted them if facts develop that differ significantly from the facts assumed when they were issued. In addition, permits and other approvals and licenses are often granted for a term that is less than the expected life of the associated facility. Licenses and permits may require periodic renewal, which may result in additional requirements being imposed by the granting agency. In addition, existing regulations may be revised or reinterpreted by federal, state, and local agencies, or these agencies may adopt new laws and regulations that apply to us. We cannot predict the impact on our business and operating results of any such actions by these agencies.
If we are unable to recover costs of complying with regulations or other associated costs in customer rates in a timely manner, or if we are unable to obtain, renew, or comply with these governmental permits, approvals, authorizations, certificates, or licenses, our results of operations and financial condition could be materially and adversely affected.
2024 Form 10-K 16
Wisconsin Public Service Corporation
We face significant costs to comply with existing and future environmental laws and regulations.
Our operations are subject to extensive and evolving federal, state, and local environmental laws, regulations, and permit requirements related to, among other things, air emissions (including, but not limited to: CO2, methane, mercury, SO2, and NOx), protection of natural resources, water quality, wastewater discharges, and management of hazardous and toxic substances and solid wastes and soils. The EPA has recently adopted and implemented new environmental regulations, which include regulations that govern the emission of NOx, ozone, fine particulates, and other air pollutants under the CAA through the NAAQS, climate change, other air quality regulations, and water quality regulations. For example, in 2024, the EPA revised the effluent guidelines for steam electric generating plants, published a final rule lowering the PM limit under the MATS, lowered the primary (health-based) annual PM 2.5 NAAQS, published the Greenhouse Gas Power Plant Rule for fossil-fired steam generating units, issued a final Mandatory Greenhouse Gas Reporting Rule, and finalized a rule for CCR that applies to landfills, historic fill sites, and projects where CCR was placed at a power plant site. Some of these rules could be challenged or reviewed by agencies under the new presidential administration, which creates additional uncertainty. As a result of these potential challenges and reviews, existing environmental laws and regulations may be revised or new laws or regulations may be adopted at the federal, state, or local level.
We incur significant capital and operating resources to comply with environmental laws, regulations, and requirements, including costs associated with the installation of pollution control equipment; operating restrictions on our facilities; and environmental monitoring, emissions fees, and permits at our facilities. The operation of emission control equipment and compliance with rules regulating our intake and discharge of water could also increase our operating costs and reduce the generating capacity of our power plants. These regulations may create substantial additional costs in the form of taxes or emission allowances and could affect the availability and/or cost of fossil fuels and our ability to continue operating certain generating units. Failure to comply with these laws, regulations, and requirements, even if caused by factors beyond our control, may result in the assessment of civil or criminal penalties and fines. We continue to assess the potential cost of complying, and to explore different alternatives in order to comply, with these and other environmental regulations.
As a result of these compliance costs and other factors, certain of our coal-fired electric generating facilities have become uneconomical to maintain and operate, which has resulted in these units being retired or converted to an alternative type of fuel. As part of WEC Energy Group's commitment to a cleaner energy future, we have already retired approximately 400 MWs of fossil-fueled generation since the beginning of 2018. WEC Energy Group expects to retire approximately 1,200 MWs of additional coal-fired generation by the end of 2031, and plans to replace a portion of the retired capacity by building and owning zero-carbon-emitting renewable and reliable, efficient natural gas generation facilities. We have also started implementing co-firing with natural gas at certain of our coal-fired units and are evaluating the conversion to natural gas.
We are also subject to significant liabilities related to the investigation and remediation of environmental impacts at certain of our current and former facilities and at third-party owned sites. We accrue liabilities and defer costs (recorded as regulatory assets) incurred in connection with our former manufactured gas plant sites. These costs include all costs incurred to date that we expect to recover, management's best estimates of future costs for investigation and remediation and related legal expenses, and are net of amounts recovered (or that may be recovered) from insurance or other third parties. Due to the potential for the imposition of stricter standards and greater regulation in the future, the possibility that other potentially responsible parties may not be willing or financially able to contribute to cleanup costs, a change in conditions or the discovery of additional contamination, our remediation costs could increase, and the timing of our capital and/or operating expenditures in the future may accelerate or could vary from the amounts currently accrued.
Litigation over environmental issues and claims of various types, including property damage, personal injury, common law nuisance, and citizen enforcement of environmental laws and regulations, occurs frequently throughout the United States. This litigation has included claims for damages alleged to have been caused by GHG and other emissions and exposure to regulated substances and/or requests for injunctive relief in connection with such matters. In addition to claims relating to our current facilities, we may also be subject to potential liability in connection with the environmental condition of facilities that we previously owned and operated, regardless of whether the liabilities arose before, during, or after the time we owned or operated these facilities. If we fail to comply with environmental laws and regulations or cause (or caused) harm to the environment or persons, that failure or harm may result in the assessment of civil penalties and damages against us. The incurrence of a material environmental liability or a material judgment in any action for personal injury or property damage related to environmental matters could have a material adverse effect on our results of operations and financial condition.
In the event we are not able to recover all of our environmental expenditures and related costs from our customers in the future, our results of operations and financial condition could be adversely affected. Further, increased costs recovered through rates could
2024 Form 10-K 17
Wisconsin Public Service Corporation
contribute to reduced demand for electricity and natural gas, which could adversely affect our results of operations, cash flows, and financial condition.
Our operations, capital expenditures, and financial results may be affected by the impact of greenhouse gas legislation, regulation, and emission reduction goals.
There has been significant attention to issues concerning climate change as well as activism from certain stakeholders, including institutional investors and other sources of financing, to accelerate the transition to lower and limit GHG emissions. The EPA and some states have adopted and are implementing regulations to restrict emissions of GHGs. There have also been increasing efforts to introduce and adopt electrification initiatives and/or mandates and other efforts to reduce or eliminate reliance on natural gas as an energy source.
Costs associated with such legislation, regulation, and emission reduction goals could be significant within our electric and natural gas operations. New or additional GHG regulations, at either the federal or state level, may cause our environmental compliance spending to differ materially from the amounts currently estimated. There is no guarantee that we will be allowed to fully recover costs incurred to comply with these and other federal and state regulations or that cost recovery will not be delayed or otherwise conditioned. These regulations, as well as changes in the fuel markets and advances in technology, could make additional electric generating units uneconomic to maintain or operate, may impact how we operate our existing fossil-fueled power plants, and could cause us to retire and replace units earlier than planned under the WEC Energy Group capital plan, which could lead to a possible loss on abandonment and reduced revenues.
In a movement toward electrification, certain states and municipalities near our service territory have passed legislation or are considering ordinances banning natural gas used in new construction in order to limit GHG emissions. There have also been efforts to restrict residential natural gas-fired appliances. Future local, statewide, or nationwide actions like these to regulate GHG emissions could increase the price of natural gas, reduce the demand for natural gas, cause us to accelerate the replacement and/or updating of our natural gas delivery system, and adversely affect our ability to operate our natural gas facilities. A significant increase in the price of natural gas may increase rates for our natural gas customers, which could also reduce natural gas demand and revenues. The adoption of electrification initiatives and/or mandates could also result in an increase in electrical demand and increased investment costs for existing or new electrical systems. These types of initiatives and/or mandates could result in increased costs associated with permitting and siting of new technologies and delayed installation and start-up timelines. In addition, financial investments in older carbon intensive technologies may not be fully realized.
WEC Energy Group has set goals to achieve reductions in carbon emissions from its electric generation fleet, which includes us, by 60% by the end of 2025 and by 80% by the end of 2030, both from a 2005 baseline. Over the longer term, the target for WEC Energy Group's generation fleet is to be net carbon neutral by 2050. WEC Energy Group has a goal to eliminate coal as an energy source by the end of 2032.
We continue to monitor the financial and operational feasibility of taking more aggressive action to further reduce GHG emissions in order to limit future global temperature increases. WEC Energy Group continues to focus on methane emission reductions by improving its natural gas distribution systems. WEC Energy Group set a target across its natural gas distribution operations, including our operations, to achieve net-zero methane emissions by the end of 2030.
The ability to achieve these reductions in CO2 and methane emissions depends on many external factors, including the ability to make operating refinements, the retirement of less efficient generating units, the development of relevant energy technologies, the use of RNG throughout our natural gas utility systems, the ability to procure RTCs, legislative and regulatory support for renewable generation, the ability to maintain reliability with demand growth, and the ability of WEC Energy Group to execute its capital plan. These efforts could impact how we operate our electric generating units and natural gas facilities and lead to increased competition and regulation, all of which could have a material adverse effect on our operations and financial condition. There can be no guarantee that WEC Energy Group will achieve its targets.
Changes in tax legislation, IRS audits, or our inability to use certain tax benefits and carryforwards, may adversely affect our financial condition, results of operations, and cash flows, as well as our credit ratings.
Tax legislation and regulations can adversely affect, among other things, our financial condition, results of operations, cash flows, liquidity, and credit ratings. Future changes to corporate tax rates or policies, including under Treasury Regulations and guidance issued in connection with the IRA, could require us to take material charges against earnings. Such changes include, among other things, increasing the federal corporate income tax rate, disallowing or limiting the use of certain tax benefits and carryforwards,
2024 Form 10-K 18
Wisconsin Public Service Corporation
limiting interest deductions, and altering the expensing of capital expenditures. Our inability to manage these changes, an adverse determination by one of the applicable taxing jurisdictions, or additional interpretations, implementing regulations, amendments, or technical corrections by the Treasury Department, the IRS, or state income tax authorities, could significantly impact our financial results and cash flows.
We have significantly reduced our federal and state income tax liabilities in the past through tax credits, net operating losses, and charitable contribution deductions. A reduction in or disallowance of these tax benefits could adversely affect our earnings and cash flows. We have not fully used these allowed tax benefits in our previous tax filings and have carried them forward to use against future taxable income. Our inability to generate sufficient taxable income in the future to fully use these tax carryforwards before they expire, or to transfer future tax credits as discussed below, could significantly affect our tax obligations and financial results.
In addition, we have invested, and plan to continue to invest, in renewable energy generating facilities. These facilities generate PTCs or ITCs that we can use to reduce our federal tax obligations. Under the IRA, a transferability option also allows us to sell these tax credits to third parties. This is a relatively new market that may require additional regulations and guidance from taxing authorities. The amount of tax credits we earn depends on available government incentives and policies, the amount of electricity produced, the applicable tax credit rate, or the amount of the investment in qualifying property. Any reductions or eliminations of tax credits or other governmental incentives that promote renewable energy generating facilities, including the repeal or amendment of portions of the IRA and the executive order issued by the new presidential administration, could make it less conducive for the development and operation of renewable energy facilities. In addition, a variety of operating and economic factors, including transmission constraints, adverse weather conditions, and breakdown or failure of equipment, could significantly reduce the PTCs generated by the renewable projects we have invested in, resulting in a material adverse impact on our financial condition and results of operations. The imposition of additional taxes, tariffs, or other assessments related to renewable energy projects or the equipment necessary to generate or deliver it, as well as any reductions or eliminations of tax credits or other governmental incentives that promote renewable energy generating facilities, may also limit our ability to make further investments in renewable energy generating facilities or reduce the returns on our existing investments.
We are also uncertain as to how credit rating agencies, capital markets, the FERC, or state public utility commissions will treat any future changes to federal or state tax legislation. These impacts could subject us to credit rating downgrades. In addition, certain financial metrics used by credit rating agencies, such as our funds from operations-to-debt percentage, could be negatively impacted by changes in federal or state income tax legislation.
We could be subject to higher costs and penalties as a result of mandatory reliability standards.
We are subject to mandatory reliability and critical infrastructure protection standards established by the North American Electric Reliability Corporation and enforced by the FERC. The critical infrastructure protection standards focus on controlling access to critical physical and cybersecurity assets. Compliance with the mandatory reliability standards could subject us to higher operating costs. If we are found to be in noncompliance with the mandatory reliability standards, we could be subject to sanctions, including substantial monetary penalties, or damage to our reputation.
Risks Related to the Operation of Our Business
Public health crises, including epidemics and pandemics, could adversely affect our business functions, financial condition, liquidity, and results of operations.
Public health crises, including epidemics and pandemics, and any related government responses may adversely impact the economy and financial markets and could have a variety of adverse impacts on us, including a decrease in revenues; increased bad debt expense; increases in past due accounts receivable balances; and access to the capital markets at unreasonable terms or rates.
Public health crises and any related government responses could also impair our ability to develop, construct, and operate facilities. Risks include extended disruptions to supply chains and inflation, resulting in increased costs for labor, materials, and services, which could adversely impact WEC Energy Group's ability to implement its corporate strategy. We may also be adversely impacted by labor disruptions and productivity as a result of infections, employee attrition, and a reduced ability to replace departing employees as a result of employees who leave or forego employment to avoid any required precautionary measures.
Despite our efforts to manage the impacts of public health crises which may occur in the future, the extent to which they may affect us depends on factors beyond our knowledge or control. As a result, we are unable to determine the potential impact any such public health crises may have on our business plans and operations, liquidity, financial condition, and results of operations.
2024 Form 10-K 19
Wisconsin Public Service Corporation
Our operations are subject to risks arising from the reliability of our electric generation, transmission, and distribution facilities, natural gas infrastructure facilities, renewable energy facilities, and other facilities, as well as the reliability of third-party transmission providers.
Our financial performance depends on the successful operation of our electric generation and transmission, natural gas and electric distribution facilities, and renewable energy facilities. The operation of these facilities involves many risks, including operator error and the breakdown or failure of equipment or processes.
Potential breakdown or failure may occur due to severe weather (i.e., storms, tornadoes, floods, droughts, etc.); catastrophic events (i.e., fires, earthquakes, and explosions); public health crises; significant changes in water levels in waterways; fuel supply or transportation disruptions; accidents; employee labor disputes; construction delays or cost overruns; delays in the replacement of aging infrastructure; shortages of or delays in obtaining equipment, material, and/or labor; performance below expected levels; operating limitations that may be imposed by environmental or other regulatory requirements; terrorist or other physical attacks; or cybersecurity intrusions. Any of these events could lead to substantial financial losses, including increased maintenance costs, and unanticipated capital expenditures. Because our electric generation and renewable energy facilities are interconnected with third-party transmission facilities, the operation of our facilities could also be adversely affected by events impacting their systems. Unplanned outages at our power plants may reduce our revenues, cause us to incur significant costs if we are required to operate our higher cost electric generators or purchase replacement power to satisfy our obligations, and could result in additional maintenance expenses.
Insurance, warranties, performance guarantees, or recovery through the regulatory process may not cover any or all of these lost revenues or increased expenses, which could adversely affect our results of operations and cash flows.
Our natural gas operations depend upon the availability of adequate interstate pipeline transportation capacity and natural gas.
We purchase almost all of our natural gas supply from interstate sources that must be transported to our service territory. Interstate pipeline companies transport the natural gas to our natural gas systems under firm service agreements that are designed to meet the requirements of our core markets. A significant disruption to interstate pipelines capacity or reduction in natural gas supply due to events including, but not limited to, operational failures or disruptions, hurricanes, tornadoes, floods, freeze-off of natural gas wells, terrorist or physical attacks, cyberattacks, other acts of war, or legislative or regulatory actions or requirements, including remediation related to integrity inspections or regulations and laws enacted to address climate change or other environmental matters, could reduce the normal interstate supply of natural gas and thereby significantly disrupt our operations and/or reduce earnings.
Our operations are subject to various conditions that can result in fluctuations in energy sales to customers, including customer growth and general economic conditions in our service area, varying weather conditions, and energy conservation efforts.
Our results of operations and cash flows are affected by the demand for electricity and natural gas, which can vary greatly based upon:
•Fluctuations in customer growth and general economic conditions in our service area. Customer growth and energy use can be negatively impacted by population declines as well as economic factors in our service territory, including workforce reductions, stagnant wage growth, changing levels of support from state and local government for economic development, business closings, and reductions in the level of business investment. Our electric and natural gas operations are impacted by economic cycles and the competitiveness of the commercial and industrial customers we serve. Any economic downturn, disruption of financial markets, or reduced incentives by state government for economic development could adversely affect the financial condition of our customers and demand for their products or services. These risks could directly influence the demand for electricity and natural gas as well as the need for additional power generation and generating facilities. We could also be exposed to greater risks of accounts receivable write-offs if customers are unable to pay their bills.
•Weather conditions. Demand for electricity is greater in the summer and winter months when cooling and heating is necessary. In addition, demand for natural gas peaks in the winter heating season. As a result, our overall results may fluctuate substantially on a seasonal basis. In addition, milder temperatures during the summer cooling season and during the winter heating season may result in lower revenues and net income.
•Our customers' continued focus on energy conservation. Our customers' use of electricity and natural gas has decreased as a result of continued individual conservation efforts, including the use of more energy efficient technologies, and could be further reduced by new building codes, DERs, energy storage technology, and private solar. Customers could also voluntarily reduce their
2024 Form 10-K 20
Wisconsin Public Service Corporation
consumption of energy in response to decreases in their disposable income and increases in energy prices. Conservation of energy can be influenced by certain federal and state programs that are intended to influence how consumers use energy. For example, several states, including Wisconsin, have adopted energy efficiency targets to reduce energy consumption.
As part of our planning process, we estimate the impacts of changes in customer growth and general economic conditions, weather, and customer energy conservation efforts, but risks still remain. The growth of data centers and development of associated technology may make it more difficult to accurately forecast customer demand or to recover additional costs. Any of these matters, as well as any regulatory delay in adjusting rates as a result of reduced sales from effective conservation measures or the adoption of new technologies, could adversely impact our results of operations and financial condition. In addition, elimination or reduced financial support of programs that provide energy assistance to our customers, including the Low Income Home Energy Assistance Program, could impact the demand for energy and/or adversely impact our liquidity.
Our operations are subject to the effects of global climate change.
A changing climate creates uncertainty and could result in broad changes, both physical and financial in nature, to our service territory. If climate changes occur that result in extreme temperatures in our service territory, our financial results could be adversely impacted by lower electric and natural gas usage and higher natural gas costs. An extreme weather event could result in downed wires and poles, as well as damage to wind and solar generation facilities, or other operating equipment. This could result in us incurring significant restoration costs, and foregoing sales of energy and lost revenues. Extreme weather in summer could cause electric load to be interrupted or certain customers to be curtailed who participate in load management programs. Additionally, an extreme weather event could also cause the cost of natural gas purchased for our natural gas utility customers and for the use of fuel at our generation facilities to be temporarily driven significantly higher than our normal winter weather expectations. Although we have a regulatory mechanism in place for recovering all prudently incurred natural gas costs, our regulators could disallow recovery or order the refund of any costs determined to be imprudent.
In addition, our operations could be adversely affected and our facilities placed at greater risk of damage should changes in global climate produce, among other possible conditions, unusual variations in temperature and weather patterns, which could result in more intense, frequent and extreme weather events, such as storms, including derecho events, with high winds, lightning, and hail, floods, drought, wild fires, tornadoes, snow and ice storms, or abnormal levels of precipitation. Extreme weather may result in unexpected increases in customer load, requiring us to procure additional power at wholesale prices for our retail operations, unpredictable curtailment of customer load by MISO to maintain grid reliability, or other grid reliability issues. Any of these events could lead to substantial financial losses including increased maintenance costs or unanticipated capital expenditures. The cost of storm restoration efforts may also not be fully recoverable through the regulatory process.
Our corporate strategy may be impacted by policy and legal, technology, market, and reputational risks and opportunities that are associated with the transition to lower GHG emissions. In addition, changes in policy to combat climate change, including mitigation and adaptation efforts, and technology advancement, each of which can also accelerate the implications of a transition to lower emissions, may materially adversely impact our results of operations and cash flows through significant capital expenditures and investments in renewable generation.
Our operations and future results may be impacted by changing expectations and demands of our customers, regulators, investors, and other stakeholders.
Our ability to execute WEC Energy Group's strategy and achieve anticipated financial outcomes are influenced by the expectations of our customers, regulators, investors, and other stakeholders. Those expectations are based in part on the core fundamentals of affordability and reliability but are also increasingly focused on our ability to meet rapidly changing demands for new and varied products, services, and offerings. Additionally, the risks of global climate change continues to shape our customers’ sustainability goals and energy needs, as well as the investment and financing criteria of investors. Failure to meet these expectations or to adequately address the risks and external pressures may impact our reputation and affect our ability to achieve favorable outcomes in future rate cases or our results of operations. The new presidential administration's efforts to roll back certain climate and diversity, equity, and inclusion policies and programs may conflict with the expectations of our customers, regulators, and investors, creating additional uncertainty as we look to balance our stakeholders' competing priorities, and could lead to litigation and government investigations. Furthermore, the increasing use of social media may accelerate and increase the potential scope of negative publicity we might receive and could increase the negative impact on our reputation, business, results of operations, and financial condition.
2024 Form 10-K 21
Wisconsin Public Service Corporation
As it relates to electric generation, a diversified fleet with increasingly clean generation resources may facilitate more efficient financing and lower costs. Conversely, jurisdictions utilizing more carbon-intensive generation such as coal may experience difficulty attracting certain investors and obtaining the most economical financing terms available.
Our operations and corporate strategy may be adversely affected by supply chain disruptions and inflation.
Our business is dependent on the global supply chain to ensure that equipment, materials, and other resources are available to both expand and maintain services in a safe and reliable manner. Protracted, expanding or escalating regional or international conflicts, including the conflicts involving Ukraine, Israel, and parts of the Middle East, as well as strained relationships between the United States and other countries related to such conflicts, could result in domestic and global supply chain disruptions that delay the delivery, or result in shortages of, materials, equipment, and other resources that are critical to our business operations. Failure to eliminate or manage the constraints in the supply chain may eventually impact the availability of items that are necessary to support normal operations as well as materials that are required to implement our corporate strategy for continued utility and infrastructure growth, including our renewable energy projects.
Moreover, prices of equipment, materials, and other resources have increased as a result of supply chain disruptions and may continue to increase in the future, as a result of inflation. Increases in inflation raise our costs for labor, materials, and services, and failure to secure these resources on economically acceptable terms, as well as any regulatory delay in adjusting rates to account for increased costs, may adversely impact our financial condition and results of operations.
In addition, the imposition of new tariffs, or other changes in United States trade policy, could trigger retaliatory actions by affected countries. A “trade war” of this nature or other governmental action related to tariffs or international trade agreements or policies has the potential to result in or exacerbate global supply chain disruptions and/or inflation, which could result in an adverse impact on our business operations, financial condition, and/or capital plan.
We are actively involved with multiple significant capital projects, which are subject to a number of risks and uncertainties that could adversely affect project costs and completion of construction projects.
Our business requires substantial capital expenditures for investments in, among other things, capital improvements to our electric generating facilities, electric and natural gas distribution infrastructure, LNG storage, and other projects, including projects for environmental compliance. We also expect to continue constructing and investing in renewable energy and natural gas generating facilities as part of the WEC Energy Group capital plan and its goal to be net carbon neutral by 2050. In addition, we continue to invest in technology and the development of software applications to support our business.
Achieving the intended benefits of any large construction project is subject to many uncertainties, some of which we will have limited or no control over, that could adversely affect project costs and completion time. Supply chain disruptions, including solar panel shortages and delays, increasing material costs, government tariffs, and other factors, could impact the timing of completion of our renewable projects. For example, the UFLPA's prohibition on imports of solar panels manufactured with certain silica-based products originating in Xinjiang, China, has and could delay the release of solar panels to us for our renewables projects. Additional risks include, but are not limited to, the ability to adhere to established budgets and time frames; the availability of labor or materials at estimated costs; the ability of contractors to perform under their contracts; strikes; adverse weather conditions; potential legal challenges; changes in applicable laws or regulations; rising interest rates; inflation; tariffs; the impact of public health crises; other governmental actions; continued public and policymaker support for such projects; and events in the global economy.
Certain of these projects require the approval of the PSCW. If construction of PSCW-approved projects should materially and adversely deviate from the schedules, estimates, and/or projections on which the approval was based, the PSCW may deem the additional capital costs as imprudent and disallow recovery of them through rates, and otherwise available PTCs and ITCs for renewable energy projects could be lost or lose value. Efforts to pause approvals related to wind development could threaten our ability to execute our capital plan. Other renewable energy sources, including solar developments, could also be at risk. In addition, the PSCW, in a future rate proceeding, may alter the timing or amount of certain costs for which recovery is allowed.
We sometimes incur significant engineering, design, and equipment costs in advance of receiving necessary regulatory approvals and/or siting or environmental permits. If any of these projects are canceled for any reason, including failure to receive necessary regulatory approvals and/or siting or environmental permits, significant cancellation penalties under the equipment purchase orders and construction contracts could occur. We may not be allowed to recover these penalties and other costs incurred in customer rates, which could have a material adverse effect on our results of operations. In addition, if any construction work or investments
2024 Form 10-K 22
Wisconsin Public Service Corporation
have already been recorded as an asset, an impairment may need to be recorded. Despite mitigation efforts we have undertaken, we may still experience significant losses or delayed recovery of these costs.
To the extent that delays occur, costs become unrecoverable, tax credits are lost or lose value, or we or third parties with whom we invest and/or partner otherwise become unable to effectively manage and complete capital projects, our results of operations, cash flows, and financial condition may be adversely affected.
Our operations are subject to risks beyond our control, including but not limited to, cybersecurity intrusions, terrorist or other physical attacks, acts of war, or unauthorized access to personally identifiable information.
We have been subject to attempted cyber attacks from time to time, and will likely continue to be subject to such attempted attacks; however, these prior attacks have not had a material impact on our system or business operations. All of our assets and systems are potentially vulnerable to disability, failures, or unauthorized access due to physical or cybersecurity intrusions caused by human error, vendor bugs, terrorist or other physical attacks (including potential attacks on our substations and other electric distribution equipment), acts of war, or other malicious acts. Cybersecurity threats could result in a full or partial disruption of our ability to generate, transmit, purchase, or distribute electricity or natural gas or cause environmental repercussions. If our assets or systems were to fail, be physically damaged, or be breached, and were not recovered in a timely manner, we may be unable to perform critical business functions, and data, including sensitive information, could be compromised. Cybersecurity attacks, including attacks targeting utility systems and other critical infrastructure, may increase during periods of heightened or escalating geopolitical tensions.
We operate in an industry that requires the use of sophisticated information technology systems and network infrastructure, which in turn control an interconnected network of generation, distribution, and transmission systems shared with third parties. A successful physical or cybersecurity intrusion may occur despite our security measures or those we require of our vendors, including compliance with reliability and critical infrastructure protection standards. Successful cybersecurity intrusions, including those targeting the electronic control systems used at our generating facilities and electric and natural gas transmission and distribution systems, could disrupt our operations and result in loss of service to customers. Attacks may come through ransomware, software updates or patches, or firmware that hackers can manipulate. These intrusions may cause unplanned outages at our power plants, which may reduce our revenues or cause us to incur significant costs if we are required to operate our higher cost electric generators or purchase replacement power to satisfy our obligations, and could result in additional maintenance expenses. The risk of such intrusions may also increase our capital and operating costs as a result of having to implement increased security measures for protection of our information technology and infrastructure.
Our continued efforts to integrate, consolidate, and streamline our operations with those of WEC Energy Group's other subsidiaries have also resulted in increased reliance on current and recently completed projects for technology systems. The failure to enhance existing information technology systems and adopt or successfully implement new technology, could adversely affect our operations. Cybersecurity threats, including those leveraging AI, continue to increase, and the security measures and preventative actions we take to reduce the risk of cybersecurity incidents and protect our systems against unauthorized access to secured data and systems may be insufficient to safeguard against all security breaches. The failure of any of these important technologies, or our inability to support, update, expand, and/or integrate these technologies with those of our affiliates, could materially and adversely impact our operations, diminish customer confidence and our reputation, materially increase the costs we incur to protect against these risks, and subject us to possible financial liability or increased regulation or litigation.
Our business requires the collection and retention of personally identifiable information of our customers and employees, who expect that we will adequately protect such information. In some cases, we rely on third-party hosted services to support our business operations. Malicious actors may target these providers to disrupt the services they provide to us, or to use those third parties to attack us. Security breaches of our or our third-party service providers' systems may expose us to a risk of loss or misuse of confidential and proprietary information. A significant theft, loss, or fraudulent use of personally identifiable information may lead to potentially large costs to notify and protect the impacted persons, and/or could cause us to become subject to significant litigation, costs, liability, fines, or penalties, any of which could materially and adversely impact our results of operations as well as our reputation with customers and regulators, among others. In addition, we may be required to incur significant costs associated with governmental actions in response to such intrusions or to strengthen our information and electronic control systems. We may also need to obtain additional insurance coverage related to the threat of such intrusions.
Threats to our systems and operations continue to emerge as new ways to compromise components into our systems or networks are developed. Any operational disruption or environmental repercussions caused by on-going or future threats to our assets and technology systems could result in a significant decrease in our revenues or significant reconstruction or remediation costs, which
2024 Form 10-K 23
Wisconsin Public Service Corporation
could materially and adversely affect our results of operations, financial condition, and cash flows. The costs of repairing damage to our facilities, operational disruptions, protecting personally identifiable information, and notifying impacted persons, as well as related legal claims, may also not be recoverable in rates, may exceed the insurance limits on our insurance policies, or, in some cases, may not be covered by insurance.
Adoption of AI technologies could adversely affect our business, reputation, or financial results.
We are using AI primarily through services provided by our third party vendors. In addition, we are exploring the use of AI, including generative AI, and its ability to enhance the services we offer. There are significant risks involved in developing and deploying AI, and there can be no assurance that the use of AI will enhance our services or be beneficial to our business, including with respect to the efficiency and resiliency of our systems. Our AI-related efforts may give rise to risks related to accuracy, bias, discrimination, intellectual property infringement or misappropriation, data privacy, and cybersecurity, among others. In addition, the adoption of AI may subject us to new or enhanced governmental or regulatory scrutiny, laws, rules, directives, or regulations governing the use of AI, as well as litigation, ethical concerns, negative customer perceptions as to automation and AI, legal liability or other complications that could adversely affect our business, reputation, or financial results. We may not be able to recover our investments in AI technology through our regulatory proceedings. Similarly, as AI continues to evolve, we may not be able to adopt and implement AI as quickly as our customers or communities desire or regulators may require. AI is a relatively new and rapidly evolving technology, and we are unable to predict all of the risks that may result from our and our vendor's adoption of AI initiatives.
Advances in technology, and legislation or regulations supporting such technology, could make our electric generating facilities less competitive and may impact the demand for natural gas.
Advances in new technologies that produce or store power or reduce power consumption are ongoing and include renewable energy technologies, customer-oriented generation, energy storage devices, and energy efficiency technologies. We generate power at central station power plants and utility-scale renewable generation facilities to achieve economies of scale and produce power at a competitive cost. Distributed generation technologies that produce power, including fuel cells, microturbines, wind turbines, solar cells, and related energy storage devices, have technologically improved and have become more cost competitive than they were in the past.
Recent legislation, including the IRA and the Infrastructure Investment and Jobs Act, has promoted the construction and cost-effectiveness of renewable energy generation, including distributed generation technologies for self-supply of electricity by our customers and third parties. Increased use of technologies such as private solar and battery storage in our service territories could reduce our recovery of fixed costs, could result in customers leaving the electric distribution system, and could cause an increase in customer net energy metering, which allows customers with private solar to receive bill credits for surplus power at the full retail amount. Over time, customer adoption of these technologies could result in us not being able to fully recover the costs and investment in generation.
Federal and state regulations and other efforts designed to promote and expand the use of distributed generation technologies also incentivize modernization of the electric distribution grid to, among other things, accommodate two-way flows of electricity and increase the grid's capacity to interconnect to these distributed generation technologies. Other legislation or regulations could be adopted supporting the use of these technologies at below cost or that permit third-party sales from such facilities, and allow these facilities to interconnect to our distribution system. There is also a risk that advances in technology will continue to reduce the costs of these alternative methods of producing power to a level that is competitive with that of central station and utility-scale renewable power production. In addition, regulatory support of co-locating generation near data centers could impact our generation planning and its related cost recovery and could cause our generation to be less cost effective.
We also cannot predict the effect that development of alternative energy sources or new technology may have on our natural gas operations, including whether subsidies of alternative energy sources by local, state, and federal governments might be expanded, or what impact this might have on the supply of or the demand for natural gas.
If these technologies become cost competitive and achieve economies of scale, our market share could be eroded, and the value of our generating facilities and natural gas distribution systems could be reduced. Advances in technology, or changes in legislation or regulations, could also change the channels through which our customers purchase or use power and natural gas, which could reduce our sales and revenues or increase our expenses.
2024 Form 10-K 24
Wisconsin Public Service Corporation
We generate and distribute electricity and transport and distribute natural gas, which involves numerous risks that may result in accidents and other operating risks and costs.
Inherent in electric generation and distribution and natural gas transportation and distribution activities are a variety of hazards and operational risks, such as leaks, accidental explosions, mechanical problems, fires, discharges or releases of toxic or hazardous substances or gases, and other environmental risks, which could materially and adversely affect our results of operations, financial condition, and cash flows. In addition, these risks could result in serious injury to employees and non-employees, loss of human life, significant damage to property, environmental pollution, impairment of operations, and substantial losses to us. The location of natural gas pipelines near populated areas could increase the level of damages resulting from these risks. These activities may subject us to litigation and/or administrative proceedings from time to time, which could result in substantial monetary judgments, fines, or penalties against us, or be resolved on unfavorable terms. Further, delays in the replacement of aging infrastructure may lead to increased costs and disruptions in operations that could also negatively impact our financial results.
We may fail to attract and retain an appropriately qualified workforce.
We operate in an industry that requires many of our employees to possess unique technical skill sets. Events such as an aging workforce without appropriate replacements, the mismatch of skill sets to future needs, or the unavailability of contract resources may lead to operating challenges or increased costs. These operating challenges include lack of resources, loss of knowledge, and a lengthy time period associated with skill development. Failure to hire and obtain replacement employees, including the ability to transfer significant internal historical knowledge and expertise to the new employees, may adversely affect our ability to manage and operate our business. If we are unable to successfully attract and retain an appropriately qualified workforce, our results of operations could be adversely affected.
Our counterparties may fail to meet their obligations, including obligations under power purchase, natural gas supply, natural gas pipeline capacity, and transportation agreements.
We are exposed to the risk that counterparties to various arrangements who owe us money, electricity, natural gas, or other commodities or services will not be able to perform their obligations. Should the counterparties to these arrangements fail to perform or if capacity is inadequate, we may be required to replace the underlying commitment at current market prices or we may be unable to meet all of our customers' electric and natural gas requirements unless or until alternative supply arrangements are put in place. In such event, we may incur losses, and our results of operations, financial position, or liquidity could be adversely affected.
We have entered into several power purchase, natural gas supply, natural gas pipeline capacity, and transportation agreements with non-affiliated companies. Revenues are dependent on the continued performance by the counterparties of their obligations under these agreements. Although we have a comprehensive credit evaluation process and contractual protections, it is possible that one or more counterparties could fail to perform their obligations. If this were to occur, we generally would expect that any operating and other costs that were initially allocated to a defaulting customer's power purchase, natural gas supply, natural gas pipeline capacity, or transportation agreement would be reallocated among our retail customers. To the extent these costs are not allowed to be reallocated by our regulators or there is any regulatory delay in adjusting rates, a counterparty default under these agreements could have a negative impact on our results of operations and cash flows.
Risks Related to Economic and Market Volatility
Our business is dependent on our ability to successfully access credit and capital markets on competitive terms and rates.
We rely on access to credit and capital markets to support our capital requirements, including expenditures for our utility infrastructure and to comply with future regulatory requirements, to the extent not satisfied by the cash flow generated by our operations. We have historically secured funds from a variety of sources, including the issuance of short-term and long-term debt securities. In addition, we rely on a committed bank credit agreement as back-up liquidity, which allows us to access the low cost commercial paper markets. The availability of credit depends upon the ability of banks providing commitments under the facility to provide funds when their obligations to do so arise. Systemic risk of the banking system and the financial markets could prevent a bank from meeting its obligations under the credit agreement.
Successful implementation of our long-term business strategies, including capital investment, is dependent upon our ability to access the capital markets, including the banking and commercial paper markets, on competitive terms and rates. Continued elevation of, or further increases in, interest rates may adversely affect our results of operations and our ability to earn our approved rate of return. High interest rates may also impair our ability to cost-effectively finance capital expenditures and to refinance maturing debt.
2024 Form 10-K 25
Wisconsin Public Service Corporation
Our access to the credit and capital markets could be limited, or our cost of capital significantly increased, due to any of the following risks and uncertainties:
•A rating downgrade;
•Failure to comply with debt covenants;
•An economic downturn or uncertainty;
•Prevailing market conditions and rules;
•Political tensions, including civil unrest and election volatility;
•Concerns over foreign economic conditions;
•Changes in tax policy;
•Changes in investment criteria of institutional investors or banks, including any policies that would limit or restrict funding for companies with fossil fuel-related investments;
•War or the threat of war; and
•The overall health and view of the utility and financial institution industries.
If any of these risks or uncertainties limit our access to the credit and capital markets or significantly increase our cost of capital, it could limit our ability to implement, or increase the costs of implementing, our business plan, which, in turn, could materially and adversely affect our results of operations, cash flows, and financial condition.
A downgrade in our credit ratings could negatively affect our ability to access capital at reasonable costs and/or require the posting of collateral.
There are a number of factors that impact our credit ratings, including, but not limited to, capital structure, regulatory environment, the ability to cover liquidity requirements, and other requirements for capital. We could experience a downgrade in ratings if the rating agencies determine that our level of business or financial risk, or that of the utility industry, has deteriorated. Changes in rating methodologies by the rating agencies could also have a negative impact on credit ratings. Any downgrade by the rating agencies could increase borrowing costs under our existing credit facility or future financings, decrease funding sources, limit the availability of adequate credit support for our operations, and trigger collateral requirements in various contracts.
The fluctuation in demand for certain commodities and their respective prices could negatively impact our operations.
Our operating and liquidity requirements are impacted by changes in the forward and current market prices of natural gas, coal, electricity, renewable energy credits, and ancillary services.
We burn natural gas in several of our electric generation plants and as a supplemental fuel at one of our coal-fired plants. In many instances the cost of purchased power is tied to the cost of natural gas. The cost of natural gas may increase because of disruptions in the supply of natural gas due to a curtailment in production or distribution, international market conditions, the demand for natural gas, and the availability of shale gas and potential regulations and/or other government action affecting its accessibility. We also burn coal at certain of our electric generation facilities. We may be obligated to pay for coal deliveries under our contracts even if our coal-fired generating facilities do not operate enough to fully utilize the amounts of coal covered by the contracts.
For Wisconsin retail electric customers, we bear the risk for the recovery of fuel and purchased power costs within a symmetrical 2% fuel tolerance band compared to the forecast of fuel and purchased power costs established in our rate structure. Prudently incurred fuel and purchased power costs are recovered dollar-for-dollar from our wholesale electric customers. We receive dollar-for-dollar recovery of prudently incurred natural gas costs from our natural gas customers.
Changes in the demand for commodities and their respective prices could result in:
•Higher working capital requirements, particularly related to natural gas inventory, accounts receivable, and cash collateral postings;
•Reduced profitability to the extent that lower revenues, higher fuel costs, increased bad debt, and higher interest expense are not recovered through rates;
•Higher rates charged to our customers, which could impact our competitive position;
•Reduced demand for energy, which could impact revenues and operating expenses; and
•Shutting down of generation facilities if the cost of generation exceeds the market price for electricity.
2024 Form 10-K 26
Wisconsin Public Service Corporation
We may not be able to obtain an adequate supply of coal, which could limit our ability to operate our coal-fired facilities.
We operate jointly-owned coal-fired electric generating units. Although we generally carry sufficient coal inventory at our generating facilities to protect against an interruption or decline in supply, there can be no assurance that the inventory levels will be adequate. While we have coal supply and transportation contracts in place, we cannot assure that the counterparties to these agreements will be able to fulfill their obligations to supply coal to us or that we will be able to take delivery of all the coal volume contracted for. Coal deliveries may occasionally be restricted because of rail congestion and maintenance, derailments, weather, public health crises, and supplier financial hardship as a result of decreased demand for coal.
If we are unable to obtain our coal requirements under our coal supply and transportation contracts, we may be required to purchase coal at higher prices or we may be forced to reduce generation at our jointly-owned coal-fired units, which could lead to increased fuel costs. The increase in fuel costs could result in either reduced margins on net sales into the MISO Energy Markets, a reduction in the volume of net sales into the MISO Energy Markets, and/or an increase in net power purchases in the MISO Energy Markets. There is no guarantee that we would be able to fully recover any increased costs in rates or that recovery would not otherwise be delayed, either of which could adversely affect our results of operations and cash flows.
Our use of derivative contracts could result in financial losses.
We use derivative instruments such as swaps, options, futures, and forwards to manage commodity price exposure. We could recognize financial losses as a result of volatility in the market value of these contracts or if a counterparty fails to perform. These risks are managed through risk management policies, which might not work as planned and cannot entirely eliminate the risks associated with these activities. In addition, although our hedging programs must be approved by the PSCW, derivative contracts entered into for hedging purposes might not offset the underlying exposure being hedged as expected, resulting in financial losses. In the absence of actively quoted market prices and pricing information from external sources, the value of these financial instruments can involve management's judgment or use of estimates. Changes in the underlying assumptions or use of alternative valuation methods could affect the reported fair value of these contracts.
Restructuring in the regulated energy industry and competition in the retail and wholesale markets could have a negative impact on our business and revenues.
The regulated energy industry continues to experience significant structural changes. Deregulation or other changes in law in Wisconsin could allow third-party suppliers to contract directly with customers for their natural gas and electric supply requirements. In addition, legislation or regulation that supports distributed energy technologies or that allows third party sales from such technologies could result in further competition. This increased competition in the retail and wholesale markets could have a material adverse financial impact on us.
The FERC continues to support the existing RTOs that affect the structure of the wholesale market within these RTOs. In connection with its status as a FERC-approved RTO, MISO implemented bid-based energy markets that are part of the MISO Energy Markets. All market participants, including us, must submit day-ahead and/or real time bids and offers for energy at locations across the MISO region. MISO then calculates the most efficient solution for all of the bids and offers made into the market that day and establishes an LMP that reflects the market price for energy. We are required to follow MISO's instructions when dispatching generating units to support MISO's responsibility for maintaining the stability of the transmission system. MISO also implemented an ancillary services market for operating reserves that schedules energy and ancillary services at the same time as part of the energy market, allowing for more efficient use of generation assets in the MISO Energy Markets. These market designs continue to have the potential to increase the costs of transmission, the costs associated with inefficient generation dispatching, the costs of participation in the MISO Energy Markets, and the costs associated with estimated payment settlements.
The FERC rules related to transmission are designed to facilitate competition in the wholesale electricity markets among regulated utilities, non-utility generators, wholesale power marketers, and brokers by providing greater flexibility and more choices to wholesale customers, including initiatives designed to encourage the integration of renewable sources of supply. In addition, along with transactions contemplating physical delivery of energy, financial laws and regulations impact hedging and trading based on futures contracts and derivatives that are traded on various commodities exchanges, as well as over-the-counter. Technology changes in the power and fuel industries also have significant impacts on wholesale transactions and related costs. We currently cannot predict the impact of these and other developments or the effect of changes in levels of wholesale supply and demand, which are driven by factors beyond our control.
2024 Form 10-K 27
Wisconsin Public Service Corporation
Volatility in the securities markets, interest rates, changes in assumptions, market conditions, and other factors may impact the performance of our benefit plan holdings and other investment funds.
We have significant obligations related to pension and OPEB plans. If WEC Energy Group is unable to successfully manage our benefit plan assets and medical costs, our cash flows, financial condition, or results of operations could be adversely impacted. Our cost of providing these plans is dependent upon a number of factors, including actual plan experience, changes made to the plans, and assumptions concerning the future. Types of assumptions include earnings on plan assets, discount rates, the level of interest rates used to measure the required minimum funding levels of the plans, future government regulation, estimated withdrawals by retirees, and our required or voluntary contributions to the plans. Plan assets are subject to market fluctuations and may yield returns that fall below projected return rates. In addition, medical costs for both active and retired employees may increase at a rate that is significantly higher than we currently anticipate. Our funding requirements could be impacted by a decline in the market value of plan assets, changes in interest rates, changes in demographics (including the number of retirements), or changes in life expectancy assumptions.
General Risks
We may be unable to obtain insurance on acceptable terms or at all, and the insurance coverage we do obtain may not provide protection against all significant losses.
Our ability to obtain insurance, as well as the cost and coverage of such insurance, could be affected by developments affecting our business; international, national, state, or local events; and the financial condition of insurers and our contractors that are required to acquire and maintain insurance for our benefit. Insurance coverage may not continue to be available at all or at rates or terms similar to those presently available to us. In addition, our insurance may not be sufficient or effective under all circumstances and against all hazards or liabilities to which we may be subject. Any losses for which we are not fully insured or that are not covered by insurance at all could materially adversely affect our results of operations, cash flows, and financial position.

---

ITEM 1B. UNRESOLVED STAFF COMMENTS
ITEM 1B. UNRESOLVED STAFF COMMENTS
None.

---

ITEM 2. PROPERTIES
ITEM 2. PROPERTIES
We own our principal properties outright. However, the major portion of our electric utility distribution lines and natural gas utility distribution mains and services are located on or under streets and highways, on land owned by others, and are generally subject to granted easements, consents, or permits.
Electric Facilities
The following table summarizes information on our electric generation facilities, including wholly owned and jointly owned facilities, as of December 31, 2024:
Name Location Fuel Number of Generating Units Capacity In MW (1)
Natural gas-fired plants
Fox Energy Center Wrightstown, WI Natural Gas 3 581
De Pere Energy Center De Pere, WI Natural Gas/Oil 1 168
West Marinette Power Plant Marinette, WI Natural Gas 3 159
Whitewater Whitewater, WI Natural Gas/Oil 1 118 (2)
Pulliam Green Bay, WI Natural Gas 1 85
Weston Rothschild, WI Natural Gas 7 65 (2)
Total natural gas-fired plants 16 1,176
Coal-fired plants
Weston Rothschild, WI Coal 2 708 (2) (5)
Columbia Portage, WI Coal 2 308 (2) (5)
Total coal-fired plants 4 1,016
Wind facilities
Crane Creek Wind Park Howard County, IA Wind 66 99
Red Barn Grant County, WI Wind 28 82 (2)
Forward Wind Fond du Lac County, WI Wind 86 62 (2)
Total wind facilities 180 243
Solar facilities
Two Creeks Manitowoc County WI Solar 48 100 (2)
Badger Hollow I Iowa County, WI Solar 41 100 (2)
Paris Kenosha County, WI Solar 53 30 (2)
DER facility Oneida County, WI Solar 3 8 (6)
Total solar facilities 145 238
Other renewable facilities
Hydro plants (17 in number) WI Hydro 50 46 (3) (4)
Total other renewable facilities 50 46
Total system 395 2,719
(1) Capacity for our electric generation facilities, other than wind and solar generating facilities, is based on rated capacity, which is the net power output under average operating conditions with equipment in an average state of repair as of a given month in a given year. Values are primarily based on the net dependable expected capacity ratings for summer 2025 established by tests and may change slightly from year to year. The summer period is the most relevant for capacity planning purposes. This is a result of continually reaching demand peaks in the summer months, primarily due to air conditioning demand. Capacity for wind generating facilities is based on nameplate capacity, which is the amount of energy a turbine should produce at optimal wind speeds. Capacity for solar generating facilities is based on nameplate capacity, which is the maximum output that a generator should produce at continuous full power.
(2) We jointly own these facilities with various other unaffiliated entities. The capacity indicated for each of these units is equal to our portion of total plant capacity based on its percent of ownership. See Note 8, Jointly Owned Utility Facilities, for more information.
(3) All of our hydroelectric facilities follow FERC guidelines and/or regulations.
(4) WRPC owns and operates the Castle Rock and Petenwell units. We hold a 50.0% ownership interest in WRPC and are entitled to 50.0% of the total capacity at Castle Rock and Petenwell. Our share of capacity for Castle Rock and Petenwell is 7.0 MWs and 10.3 MWs, respectively.
(5) WEC Energy Group expects to retire approximately 1,200 MWs of additional coal-fired generation, which includes the planned retirements of the jointly-owned Columbia Units 1-2 while investigating conversion of at least one unit to natural gas, and Weston Unit 3.
2024 Form 10-K 30
Wisconsin Public Service Corporation
(6) DER facilities are distribution system interconnected solar projects that are typically 5-10 MWs each.
As of December 31, 2024, we operated approximately 13,700 miles of overhead distribution lines and approximately 9,400 miles of underground distribution cable, as well as 117 electric distribution substations and approximately 306,400 line transformers.
Natural Gas Facilities
At December 31, 2024, our natural gas properties were located in northeastern Wisconsin and consisted of the following:
•Approximately 8,500 miles of natural gas distribution mains,
•Approximately 250 miles of natural gas transmission mains,
•Approximately 317,800 natural gas lateral services, and
•Approximately 90 natural gas distribution and transmission gate stations.
Our natural gas distribution and gas storage systems included distribution and transmission mains connected to the pipeline transmission systems of ANR Pipeline Company, Great Lakes Transmission Company, Guardian Pipeline L.L.C., and Vector Pipeline.
We also own office buildings, natural gas regulating and metering stations, and major service centers, including garage and warehouse facilities, in certain communities we serve. Where distribution lines and services and natural gas distribution mains and services occupy private property, we have in some, but not all instances, obtained consents, permits, or easements for these installations from the apparent owners or those in possession of those properties, generally without an examination of ownership records or title.

---

ITEM 3. LEGAL PROCEEDINGS
ITEM 3. LEGAL PROCEEDINGS
In addition to those legal proceedings discussed in Note 21, Commitments and Contingencies, and Note 23, Regulatory Environment, we are currently, and from time to time, subject to claims and suits arising in the ordinary course of business. Although the results of these additional legal proceedings cannot be predicted with certainty, management believes, after consultation with legal counsel, that the ultimate resolution of these proceedings will not have a material impact on our financial statements.

---

ITEM 4. MINE SAFETY DISCLOSURE
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
2024 Form 10-K 31
Wisconsin Public Service Corporation
PART II

---

ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
There is no established public trading market for our common stock, as Integrys, a wholly owned subsidiary of WEC Energy Group, owns all of our outstanding common stock. See Note 11, Common Equity, for more information.

---

ITEM 6. SELECTED FINANCIAL DATA
ITEM 6. RESERVED

---

ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
CORPORATE DEVELOPMENTS
Introduction
We are an electric and natural gas utility and an indirect wholly owned subsidiary of WEC Energy Group. We derive revenues primarily from the distribution and sale of electricity and natural gas to retail customers in Wisconsin. We also provide wholesale electric service to numerous utilities and cooperatives for resale. We conduct our business primarily through our utility reportable segment. See Note 20, Segment Information, for more information on our reportable business segments.
Corporate Strategy
Our goal is to continue to build and sustain long-term value for our customers and WEC Energy Group's shareholders by focusing on the fundamentals of our business: environmental stewardship; reliability; operating efficiency; financial discipline; exceptional customer care; and safety. WEC Energy Group's capital plan, provides a roadmap to achieve this goal. It is an aggressive plan to cut emissions, maintain superior reliability, deliver significant savings for customers, and grow WEC Energy Group's and our investment in the future of energy.
Throughout its strategic planning process, WEC Energy Group takes into account important developments, risks and opportunities, including new technologies, customer preferences and affordability, energy resiliency efforts, and sustainability.
Creating a Sustainable Future
WEC Energy Group's capital plan includes the retirement of older, fossil-fueled generation, to be replaced with zero-carbon-emitting renewables and reliable, efficient natural gas-fired generation at its electric utilities, including us. The retirements are intended to address compliance with the EPA Clean Air rules as well as contribute to meeting WEC Energy Group's and our goals to reduce CO2 emissions from electric generation. When taken together, the retirements and new investments in renewables and reliable, efficient natural gas generation should better balance supply with demand, while helping to address compliance and maintaining reliable, affordable energy for our customers.
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 continuing to make operating refinements, retiring less efficient generating units, and executing its capital plan. Over the longer term, the target for its generation fleet is to be net carbon neutral by 2050.
As part of our path toward these goals, we plan to co-fire with natural gas at Weston Unit 4. By the end of 2030, WEC Energy Group expects to use coal as a backup fuel only, and believes it will be in a position to eliminate coal as an energy source by the end of 2032.
WEC Energy Group already has retired nearly 2,500 MWs of fossil-fueled generation since the beginning of 2018, which includes the 2018 retirement of the Pulliam power plant and the jointly-owned Edgewater Unit 4 generating unit. WEC Energy Group expects to retire approximately 1,200 MWs of additional coal-fired generation by the end of 2031, which includes the planned retirement of the jointly-owned Columbia Units 1 and 2 and the planned retirement of Weston Unit 3. See Note 7, Property, Plant, and Equipment, for more information related to the planned retirement of Columbia Units 1 and 2.
2024 Form 10-K 32
Wisconsin Public Service Corporation
In addition to retiring these older, fossil-fueled plants, WEC Energy Group expects to invest approximately $9.1 billion from 2025-2029 in regulated renewable energy in Wisconsin. WEC Energy Group's plan is to replace a portion of the retired capacity by building and owning zero-carbon-emitting renewable generation facilities that are anticipated to include the following new investments made by either us or WE based on specific customer needs:
•2,900 MWs of utility-scale solar;
•900 MWs of wind; and
•565 MWs of battery storage.
WEC Energy Group also plans on investing in a combination of clean, natural gas-fired generation.
For more details on the projects discussed above, see Liquidity and Capital Resources - Cash Requirements - Significant Capital Projects.
In July 2023, the PSCW approved the Renewable Pathway Pilot. This program allows our commercial and industrial customers to subscribe to a portion of a utility-scale, Wisconsin-based renewable energy generating facility for up to 40 MWs.
In August 2021, the PSCW approved pilot programs for us to install and maintain EV charging equipment for customers at their homes or businesses. We proposed modifications to these pilot programs, which were approved by the PSCW and implemented on January 1, 2025. The programs provide direct benefits to customers by removing cost barriers associated with installing EV equipment. In October 2021, subject to the receipt of any necessary regulatory approvals, WEC Energy Group pledged to expand the EV charging network within its utilities' electric service territories. In doing so, WEC Energy Group joined a coalition of utility companies in a unified effort to make EV charging convenient and widely available throughout the Midwest. The coalition WEC Energy Group joined is planning to help build and grow EV charging corridors, enabling the general public to safely and efficiently charge their vehicles.
WEC Energy Group also continues to reduce methane emissions by improving its natural gas distribution system, 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 natural gas utility systems. In 2022, we received approval from the PSCW for an RNG pilot and in 2023, we began transporting the output of local dairy farms onto our natural gas distribution systems. The RNG supplied is expected to directly replace higher-emission methane from natural gas that would have entered our pipes. In addition, subject to regulatory approval and market conditions, we expect to procure RTCs.
Reliability
We have made significant reliability-related investments in recent years, and in accordance with the WEC Energy Group capital plan, expect to continue strengthening and modernizing our generation fleet, as well as our electric and natural gas distribution networks to further improve reliability.
The construction of additional LNG facilities in Wisconsin has been proposed as part of WEC Energy Group's 2025-2029 capital plan, which includes us. The facilities would provide approximately four Bcf of natural gas supply (of which our portion is expected to be approximately two Bcf) and are expected to reduce the likelihood of constraints to WEC Energy Group's natural gas distribution system during the highest demand days of winter.
We continue to upgrade our electric and natural gas distribution systems to enhance reliability and system hardening. WEC Energy Group expects to spend approximately $4.5 billion from 2025 to 2029 on reliability related projects at its regulated utilities, which includes us, with continued investment over the next decade.
For more details, see Liquidity and Capital Resources - Cash Requirements - Significant Capital Projects.
2024 Form 10-K 33
Wisconsin Public Service Corporation
Operating Efficiency
We continually look for ways to optimize the operating efficiency of our company and will continue to do so under the WEC Energy Group capital plan. For example, we are making progress on our AMI program, replacing aging meter-reading equipment on both our network and customer property. An integrated system of smart meters, communication networks, and data management programs enables two-way communication between us and our customers. This program reduces the manual effort for disconnects and reconnects and enhances outage management capabilities.
WEC Energy Group continues to focus on integrating the resources of its businesses and finding the best and most efficient processes.
Financial Discipline
A strong adherence to financial discipline is essential to meeting our earnings projections and maintaining a strong balance sheet, stable cash flows, and quality credit ratings.
We follow an asset management strategy that focuses on investing in and acquiring assets consistent with our strategic plans, as well as disposing of assets, including property, plants, and equipment, that are no longer strategic to operations, are not performing as intended, or have an unacceptable risk profile. See Note 2, Acquisitions, for more information on our acquisitions of Whitewater and Red Barn.
Exceptional Customer Care
Our approach is driven by an intense focus on delivering exceptional customer care every day. We strive to provide the best value for our customers by demonstrating personal responsibility for results, leveraging our capabilities and expertise, and using creative solutions to meet or exceed our customers’ expectations.
A multiyear effort is driving a standardized, seamless approach to digital customer service across all of the WEC Energy Group companies. It has moved all utilities, including us, to a common platform for all customer-facing self-service options. Using common systems and processes reduces costs, provides greater flexibility and enhances the consistent delivery of exceptional service to customers.
Safety
Safety is one of our core values and a critical component of our culture. We are committed to keeping our employees and the public safe through a comprehensive corporate safety program that focuses on employee engagement and elimination of at-risk behaviors.
Under our "Target Zero" mission, we have an ultimate goal of zero incidents, accidents, and injuries. Management and union leadership work together to reinforce the Target Zero culture. We set annual goals for safety results as well as measurable leading indicators, in order to raise awareness of at-risk behaviors and situations and guide injury-prevention activities. All employees are encouraged to report unsafe conditions or incidents that could have led to an injury. Injuries and tasks with high levels of risk are assessed, and findings and best practices are shared across the WEC Energy Group companies.
Our corporate safety program provides a forum for addressing employee concerns, training employees and contractors on current safety standards, and recognizing those who demonstrate a safety focus.
RESULTS OF OPERATIONS
The following discussion and analysis of our Results of Operations includes comparisons of our results for the year ended December 31, 2024 with the year ended December 31, 2023, and for the year ended December 31, 2023 with the year ended December 31, 2022.
2024 Form 10-K 34
Wisconsin Public Service Corporation
Earnings
Our earnings for the year ended December 31, 2024 were $252.9 million, compared with $260.2 million for the year ended December 31, 2023. See below for additional information on the $7.3 million decrease in earnings.
Our earnings for the year ended December 31, 2023 were $260.2 million, compared with $235.0 million for the year ended December 31, 2022. See below for additional information on the $25.2 million increase in earnings.
Non-GAAP Financial Measures
The discussion below addresses the contribution of our utility segment to net income. The discussion includes financial information prepared in accordance with GAAP, as well as utility margin, which is not a measure of financial performance under GAAP. Utility margin (operating revenues less fuel and purchased power costs and cost of natural gas sold) is a non-GAAP financial measure because it excludes certain operation and maintenance expenses applicable to revenues, as well as depreciation and amortization and property and revenue taxes.
We believe that utility margin provides a useful basis for evaluating utility operations since the majority of prudently incurred fuel and purchased power costs, as well as prudently incurred natural gas costs, are passed through to customers in current rates. As a result, management uses utility margin internally when assessing the operating performance of our utility segment as this measure excludes the majority of revenue fluctuations caused by changes in these expenses. Similarly, the presentation of utility margin herein is intended to provide supplemental information for investors regarding our operating performance.
Our utility margin may not be comparable to similar measures presented by other companies. Furthermore, this measure is not intended to replace gross margin as determined in accordance with GAAP as an indicator of operating performance. Our utility segment discussion below includes a table that provides the calculation of both gross margin as determined in accordance with GAAP and utility margin, as well as a reconciliation between the two measures.
Utility Segment Contribution to Net Income
Year Ended December 31
B (W) B (W)
(in millions) 2024 2023 2022 2024 vs 2023 2023 vs 2022
Operating revenues $ 1,560.4 $ 1,681.4 $ 1,785.2 $ (121.0) $ (103.8)
Operating expenses
Cost of sales (1)
485.3 606.8 845.1 121.5 238.3
Other operation and maintenance 440.3 434.3 362.5 (6.0) (71.8)
Depreciation and amortization 238.5 226.9 199.8 (11.6) (27.1)
Property and revenue taxes 46.9 47.4 42.4 0.5 (5.0)
Operating income 349.4 366.0 335.4 (16.6) 30.6
Other income, net 48.2 43.8 41.0 4.4 2.8
Interest expense 95.0 89.0 70.5 (6.0) (18.5)
Income before income taxes 302.6 320.8 305.9 (18.2) 14.9
Income tax expense 51.2 62.3 71.9 11.1 9.6
Net income $ 251.4 $ 258.5 $ 234.0 $ (7.1) $ 24.5
(1) Cost of sales includes fuel and purchased power and cost of natural gas sold.
2024 Form 10-K 35
Wisconsin Public Service Corporation
The following table shows a breakdown of other operation and maintenance:
Year Ended December 31
B (W) B (W)
(in millions) 2024 2023 2022 2024 vs 2023 2023 vs 2022
Operation and maintenance not included in line items below $ 210.6 $ 206.3 $ 206.8 $ (4.3) $ 0.5
Transmission (1)
162.4 161.8 133.4 (0.6) (28.4)
Regulatory amortizations and other pass through expenses (2)
69.8 66.2 40.8 (3.6) (25.4)
Earnings sharing mechanism (3)
(2.5) - (21.6) 2.5 (21.6)
Other - - 3.1 - 3.1
Total other operation and maintenance $ 440.3 $ 434.3 $ 362.5 $ (6.0) $ (71.8)
(1) Represents transmission expense that we are authorized to collect in rates. The PSCW has approved escrow accounting for ATC and MISO network transmission expenses. As a result, we defer as a regulatory asset or liability, the difference between actual transmission costs and those included in rates until recovery or refund is authorized in a future rate proceeding. During 2024, 2023, and 2022, $175.4 million, $160.2 million, and $155.0 million, respectively, of costs were billed to us by transmission providers.
During 2022, we amortized $19.0 million of the regulatory liability associated with our transmission escrow to offset certain 2022 revenue deficiencies, as approved by the PSCW in order to forego filing for 2022 base rate increases. This amortization drove the lower transmission expense during 2022.
(2) Regulatory amortizations and other pass through expenses are substantially offset in margins and therefore do not have a significant impact on net income. Effective January 1, 2023, the PSCW approved escrow accounting for pension and OPEB costs, as well as certain costs associated with our jointly-owned Columbia plant. As a result, we defer as a regulatory asset or liability, the difference between these actual costs and those included in rates until recovery or refund is authorized in a future rate proceeding.
(3) Represents operation and maintenance associated with the earnings sharing mechanism we have in place. In 2022, earnings sharing was reduced by amortization related to certain regulatory liability balances associated with our 2020 earnings sharing mechanism to offset certain 2022 revenue deficiencies, as approved by the PSCW in order to forego filing for 2022 base rate increases. See Note 23, Regulatory Environment, for more information.
The following tables provide information on delivered sales volumes by customer class and weather statistics:
Year Ended December 31
B (W) B (W)
Electric Sales Volumes (MWh - in thousands)
2024 2023 2022 2024 vs 2023 2023 vs 2022
Customer class
Residential 2,940.4 2,952.1 3,033.8 (11.7) (81.7)
Small commercial and industrial 4,028.2 4,010.1 4,039.9 18.1 (29.8)
Large commercial and industrial 3,810.9 3,830.5 3,962.6 (19.6) (132.1)
Other 21.7 22.8 26.3 (1.1) (3.5)
Total retail 10,801.2 10,815.5 11,062.6 (14.3) (247.1)
Wholesale 1,073.7 1,279.6 1,587.1 (205.9) (307.5)
Resale 754.5 376.8 332.5 377.7 44.3
Total sales in MWh 12,629.4 12,471.9 12,982.2 157.5 (510.3)
Year Ended December 31
B (W) B (W)
Natural Gas Sales Volumes (Therms - in millions)
2024 2023 2022 2024 vs 2023 2023 vs 2022
Customer class
Residential 218.8 230.0 271.2 (11.2) (41.2)
Commercial and industrial 165.7 179.0 205.5 (13.3) (26.5)
Total retail 384.5 409.0 476.7 (24.5) (67.7)
Transportation 474.8 474.3 487.4 0.5 (13.1)
Total sales in therms 859.3 883.3 964.1 (24.0) (80.8)
2024 Form 10-K 36
Wisconsin Public Service Corporation
Year Ended December 31
B (W) B (W)
Weather (Degree Days) (1)
2024 2023 2022 2024 vs 2023 2023 vs 2022
Heating (7,329 Normal)
6,015 6,544 7,387 (8.1) % (11.4) %
Cooling (554 Normal)
608 596 718 2.0 % (17.0) %
(1) Normal degree days are based on a 20-year moving average of monthly temperatures from the Green Bay, Wisconsin weather station.
Gross Margin GAAP and Utility Margin Non-GAAP
The following table summarizes our utility segment gross margin (GAAP) and reconciles gross margin (GAAP) to utility margin (non-GAAP). See "Non-GAAP Financial Measures" above for additional information regarding gross margin (GAAP) and utility margin (non-GAAP).
Year Ended December 31
B (W) B (W)
(in millions) 2024 2023 2022 2024 vs 2023 2023 vs 2022
Electric revenues $ 1,244.4 $ 1,312.1 $ 1,318.4 $ (67.7) $ (6.3)
Natural gas revenues 316.0 369.3 466.8 (53.3) (97.5)
Operating revenues 1,560.4 1,681.4 1,785.2 (121.0) (103.8)
Operating expenses
Fuel and purchased power (321.5) (388.1) (515.5) 66.6 127.4
Cost of natural gas sold (163.8) (218.7) (329.6) 54.9 110.9
Other operation and maintenance (1)
(296.2) (296.5) (273.0) 0.3 (23.5)
Depreciation and amortization (238.5) (226.9) (199.8) (11.6) (27.1)
Property and revenue taxes (46.9) (47.4) (42.4) 0.5 (5.0)
Gross margin (GAAP) 493.5 503.8 424.9 (10.3) 78.9
Other operation and maintenance (1)
296.2 296.5 273.0 (0.3) 23.5
Depreciation and amortization 238.5 226.9 199.8 11.6 27.1
Property and revenue taxes 46.9 47.4 42.4 (0.5) 5.0
Utility margin (non-GAAP) $ 1,075.1 $ 1,074.6 $ 940.1 $ 0.5 $ 134.5
(1) Operating and maintenance expenses deemed to be directly attributable to our revenue-producing activities include plant operating and maintenance expenses related to our generating units, transmission, distribution, and customer service expenses. These expenses are included in the above table to calculate gross margin as defined under GAAP.
2024 Compared with 2023
Gross margin (GAAP) at the utility segment decreased $10.3 million during 2024, compared with 2023, and utility margin (non-GAAP) increased $0.5 million during 2024, compared with 2023. Both measures were driven by:
•An $11.1 million increase in margins related to rates.
•A $1.8 million increase in margins driven by lower ash handling costs at certain of our power plants.
These increases in margins were offset by:
•A $10.2 million decrease in margins driven by a decrease in contracted volumes with one wholesale customer, as well as the expiration of a contract with another customer in December 2023.
•A $3.1 million decrease in margins related to lower retail sales volumes, driven by the impact of warmer winter weather during 2024, compared with 2023. As measured by heating degree days, 2024 was 8.1% warmer than 2023.
2024 Form 10-K 37
Wisconsin Public Service Corporation
Additionally, the decrease in gross margin (GAAP) as compared with the increase in utility margin (non-GAAP), was driven by the following items that are further described in Other Operating Expenses below:
•An $11.6 million increase in depreciation and amortization; and
•A $5.0 million increase in electric and natural gas distribution expenses; partially offset by
•An $8.7 million decrease in other operating and maintenance related to our power plants.
Other Operating Expenses (includes other operation and maintenance, depreciation and amortization, and property and revenue taxes)
Other operating expenses at the utility segment increased $17.1 million during 2024, compared with 2023. The significant factors impacting the increase in other operating expenses were:
•An $11.6 million increase in depreciation and amortization, driven by assets being placed into service as we continue to execute on our capital plan.
•A $6.1 million increase in benefit costs, primarily driven by higher stock-based compensation expense.
•A $5.0 million increase in electric and natural gas distribution expenses, primarily driven by storm restoration.
•A $3.6 million increase in regulatory amortizations and other pass through expenses, as discussed in the notes under the other operation and maintenance table above.
These increases in other operating expenses were partially offset by an $8.7 million decrease in other operating and maintenance related to our power plants, driven by the resolution of certain items as a result of our December 2024 Wisconsin rate order approved by the PSCW, as well as lower severance expense during 2024.
Other Income, Net
Other income, net increased $4.4 million during 2024, compared with 2023, driven by higher AFUDC-Equity due to continued capital investment and higher net credits from the non-service components of our net periodic pension and OPEB costs. See Note 19, Employee Benefits, for more information on our benefit costs. Higher interest income earned on amounts due from ATC for the construction of transmission infrastructure upgrades needed for new generation projects also contributed to the increase in other income. We are required to initially fund these expenditures, and ATC reimburses us when the new generation is placed in service. See Note 24, Other Income, Net, for more information.
Interest Expense
Interest expense increased $6.0 million during 2024, compared with 2023, driven by both higher average short-term debt balances and interest rates.
Income Tax Expense
Income tax expense decreased $11.1 million during 2024, compared with 2023, driven by lower pre-tax income and a $2.7 million increase in PTCs.
2023 Compared with 2022
Gross margin (GAAP) at the utility segment increased $78.9 million during 2023, compared with 2022, and utility margin (non-GAAP) increased $134.5 million during 2023, compared with 2022. Both measures were driven by:
•A $108.3 million increase in margins related to the impact of our rate order approved by the PSCW, effective January 1, 2023.
2024 Form 10-K 38
Wisconsin Public Service Corporation
•A $63.1 million year-over-year positive impact from collections of fuel and purchased power costs. Under the Wisconsin fuel rules, our margins are impacted by under- or over-collections of certain fuel and purchased power costs that are within a 2% price variance from the costs included in rates, and the remaining variance above or below the 2% price variance is generally deferred for future recovery or refund to customers. In 2022, we were unable to defer a portion of our under-collected fuel and purchased power costs due to earning an ROE in excess of the PSCW authorized amount.
These increases in margins were partially offset by:
•A $28.2 million decrease in margins related to lower sales volumes, driven by the impact of unfavorable weather during 2023, compared with 2022. As measured by cooling degree days, 2023 was 17.0% cooler than 2022. As measured by heating degree days, 2023 was 11.4% warmer than 2022.
•A $10.9 million decrease in other revenues, primarily related to a FERC order in January 2023 that eliminated reactive power compensation MISO was required to pay to generators, including us. The decrease in reactive power revenues is substantially offset by a decrease in transmission expense related to a deferral of these revenues as a component of our transmission escrow, as approved by the PSCW in June 2023 and discussed below.
Additionally, the smaller increase in gross margin (GAAP) as compared with the increase in utility margin (non-GAAP), was driven by the following items that are further described in Other Operating Expenses below:
•A $28.4 million increase in transmission expense;
•A $27.1 million increase in depreciation and amortization expense;
•A $5.4 million increase in other operating and maintenance related to our power plants; and
•A $5.0 million increase in property and revenue taxes; partially offset by
•An $11.0 million decrease in electric and natural gas distribution expenses.
Other Operating Expenses (includes other operation and maintenance, depreciation and amortization, and property and revenue taxes)
Other operating expenses at the utility segment increased $103.9 million during 2023, compared with 2022. The significant factors impacting the increase in other operating expenses were:
•A $28.4 million increase in transmission expense as approved in the PSCW's 2023 rate order, effective January 1, 2023. See the notes under the other operation and maintenance table above for more information. This amount is net of a deferral of $6.6 million approved by the PSCW in June 2023, retroactive to December 1, 2022, in response to a FERC order eliminating reactive power compensation, as discussed above.
•A $27.1 million increase in depreciation and amortization, driven by assets being placed into service as we continue to execute on our capital plan.
•A $25.4 million increase in regulatory amortizations and other pass through expenses, as discussed in the notes under the other operation and maintenance table above.
•Amortization of $21.6 million in 2022 of a regulatory liability related to our earnings sharing mechanism, as discussed in the notes under the other operation and maintenance table above.
•A $5.4 million increase in other operating and maintenance related to our power plants, driven by increases to certain plant-related regulatory assets in 2022 as a result of the December 2022 Wisconsin rate order as well as operating costs associated with Whitewater, which we purchased in January 2023. These increases were partially offset by lower severance expense during 2023.
2024 Form 10-K 39
Wisconsin Public Service Corporation
•A $5.0 million increase in property and revenue taxes, driven by higher gross receipts and property taxes during 2023, compared with 2022.
These increases in other operating expenses were partially offset by an $11.0 million decrease in electric and natural gas distribution expenses, driven by lower costs to maintain the distribution system and for storm restoration during 2023, compared with 2022.
Other Income, Net
Other income, net increased $2.8 million during 2023, compared with 2022, driven by higher AFUDC-Equity due to continued capital investment.
Interest Expense
Interest expense increased $18.5 million during 2023, compared with 2022, driven by the impact of higher long-term debt balances related to a $300.0 million issuance in November 2022, and higher short-term debt interest rates.
Income Tax Expense
Income tax expense decreased $9.6 million during 2023, compared with 2022, driven by a $13.8 million increase in PTCs, partially offset by higher pre-tax income.
Other Segment Contribution to Net Income
Year Ended December 31
B (W) B (W)
(in millions) 2024 2023 2022 2024 vs 2023 2023 vs 2022
Net income $ 1.5 $ 1.7 $ 1.0 $ (0.2) $ 0.7
LIQUIDITY AND CAPITAL RESOURCES
Overview
We expect to maintain adequate liquidity to meet our cash requirements for operation of our business and implementation of our corporate strategy through internal generation of cash from operations and access to the capital markets.
The following discussion and analysis of our Liquidity and Capital Resources includes comparisons of our cash flows for the year ended December 31, 2024 with the year ended December 31, 2023. For a similar discussion that compares our cash flows for the year ended December 31, 2023 with the year ended December 31, 2022, see Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Liquidity and Capital Resources in Part II of our 2023 Annual Report on Form 10-K, which was filed with the SEC on February 22, 2024.
Cash Flows
The following table summarizes our cash flows during the years ended December 31:
(in millions) 2024 2023 Change in 2024 Over 2023
Cash provided by (used in):
Operating activities $ 532.9 $ 575.7 $ (42.8)
Investing activities (486.9) (638.0) 151.1
Financing activities (45.9) 25.2 (71.1)
2024 Form 10-K 40
Wisconsin Public Service Corporation
Operating Activities
Net cash provided by operating activities decreased $42.8 million during 2024, compared with 2023, driven by:
•A $37.1 million decrease in cash from lower overall collections from customers during 2024, compared with 2023. This decrease was driven by the lower per-unit cost of natural gas and lower sales volumes from warmer winter weather during 2024, compared with 2023.
•A $35.3 million decrease in cash related to higher payments for other operation and maintenance expenses, driven by the timing of payments for accounts payable and higher payments for electric transmission service during 2024, compared with 2023.
These decreases in net cash provided by operating activities were partially offset by a $33.9 million increase in cash driven by lower amounts of collateral paid to counterparties during 2024, compared with 2023, as well as lower realized losses on derivative instruments recognized during 2024, compared with 2023.
Investing Activities
Net cash used in investing activities decreased $151.1 million during 2024, compared with 2023, driven by:
•The acquisition of a 90% ownership interest in Red Barn in April 2023 for $143.8 million. See Note 2, Acquisitions, for more information.
•The acquisition of a 50% ownership interest in Whitewater in January 2023 for $38.0 million. See Note 2, Acquisitions, for more information.
These decreases in net cash used in investing activities were partially offset by a $40.0 million increase in cash paid for capital expenditures, which is discussed in more detail below.
Capital Expenditures
Capital expenditures for the years ended December 31 were as follows:
(in millions) 2024 2023 Change in 2024 Over 2023
Capital expenditures $ 493.8 $ 453.8 $ 40.0
The increase in cash paid for capital expenditures during 2024, compared with 2023, was driven by higher payments for construction of renewable energy projects and upgrades to our electric distribution systems, as well as increased capital expenditures related to our electric utility operations technology. These increases in capital expenditures were partially offset by decreased payments for natural gas-fired generation that was constructed at our existing Weston power plant site, which was completed in July 2023.
See Liquidity and Capital Resources - Cash Requirements - Significant Capital Projects below for more information.
Financing Activities
Net cash related to financing activities decreased $71.1 million during 2024, compared with 2023, driven by:
•A $363.7 million decrease in cash due to $248.3 million of net repayments of commercial paper during 2024, compared with $115.4 million of net borrowings of commercial paper during 2023.
•A $90.0 million decrease in equity contributions received from our parent during 2024, compared with 2023, to balance our capital structure.
2024 Form 10-K 41
Wisconsin Public Service Corporation
These decreases in cash were partially offset by:
•A $299.8 million increase in cash due to the issuance of long-term debt during 2024. We did not issue any long-term debt during 2023.
•An $85.0 million increase in cash due to lower dividends paid to our parent during 2024, compared with 2023, to balance our capital structure.
Significant Financing Activities
For more information on our financing activities, see Note 11, Common Equity, Note 13, Short-Term Debt and Lines of Credit, and Note 14, Long-Term Debt.
Cash Requirements
We require funds to support and grow our business. Our significant cash requirements primarily consist of capital and investment expenditures, payments to retire and pay interest on long-term debt, the payment of common stock dividends to our parent, and the funding of our ongoing operations. Our significant cash requirements are discussed in further detail below.
Significant Capital Projects
We have several capital projects and acquisitions that will require significant capital expenditures over the next three years and beyond. All projected capital requirements are subject to periodic review and may vary significantly from estimates, depending on a number of factors. These factors include environmental requirements, regulatory restraints and requirements, changes in tax laws and regulations, acquisition and development opportunities, market volatility, economic trends, supply chain disruptions, inflation, and interest rates. Our estimated capital expenditures and acquisitions for the next three years are reflected below. These amounts include anticipated expenditures for environmental compliance and certain remediation issues. For a discussion of certain environmental matters affecting us, see Note 21, Commitments and Contingencies.
(in millions)
2025 $ 801.8
2026 806.4
2027 1,063.5
Total $ 2,671.7
We continue to upgrade our electric and natural gas distribution systems to enhance reliability. These upgrades include addressing our aging infrastructure, system hardening, and the AMI program. AMI is an integrated system of smart meters, communication networks, and data management systems that enable two-way communication between utilities and customers.
WEC Energy Group is committed to investing in solar, wind, battery storage, and natural gas-fired generation. Below are examples of projects that are proposed or currently underway.
•We, along with WE and an unaffiliated utility, received PSCW approval to acquire and construct Paris, a utility-scale solar-powered electric generating facility with a battery energy storage system located in Kenosha County, Wisconsin. In December 2024, the construction of the solar portion of Paris was completed. We own 30 MWs of solar generation and will own 17 MWs of battery storage of this project when construction is completed, currently expected to be in 2025. Our share of the cost of this project is estimated to be approximately $90 million.
•We, along with WE and an unaffiliated utility, received PSCW approval to acquire and construct Darien, a utility-scale solar-powered electric generating facility with a battery energy storage system. The project will be located in Rock and Walworth counties, Wisconsin and once fully constructed, we will own 37 MWs of solar generation and 12 MWs of battery storage of this project. Our share of the cost of this project is estimated to be approximately $94 million, with construction of the solar portion and battery storage expected to be completed in 2025 and 2026, respectively.
•We, along with WE and an unaffiliated utility, received PSCW approval to acquire Koshkonong, a utility-scale solar-powered electric generating facility with a battery energy storage system. The project will be located in Dane County, Wisconsin and once
2024 Form 10-K 42
Wisconsin Public Service Corporation
fully constructed, we will own 45 MWs of solar generation and 25 MWs of battery storage of this project. Our share of the cost of this project is estimated to be approximately $155 million, with construction of the solar portion and battery storage expected to be completed in 2026 and 2027, respectively.
•We plan to enhance fuel flexibility at Weston Unit 4.
•In February 2024, we, along with WE and an unaffiliated utility, filed a request with the PSCW to acquire and construct High Noon, a utility-scale solar-powered electric generating facility with a battery energy storage system. If approved, the project will be located in Columbia County, Wisconsin and once fully constructed, we will own 45 MWs of solar generation and 25 MWs of battery storage of this project. If approved, our share of the cost of this project is estimated to be approximately $147 million, with construction of the solar portion and battery storage expected to be completed in 2027.
•In September 2024, we, along with WE and an unaffiliated utility, filed a request with the PSCW to acquire Dawn Harvest, a utility-scale solar-powered electric generating facility with a battery energy storage system. If approved, the project will be located in Rock County, Wisconsin and once fully constructed, we will own 15 MWs of solar generation. If approved, our share of the cost of this project is estimated to be approximately $34 million, with construction expected to be completed in 2028.
•In September 2024, we, along with WE and an unaffiliated utility, filed a request with the PSCW to acquire Saratoga, a utility-scale solar-powered electric generating facility with a battery energy storage system and Ursa, a utility-scale solar-powered electric generating facility. If approved, Saratoga will be located in Wood County, Wisconsin and Ursa will be located in Columbia County, Wisconsin. Once fully constructed, we will own 15 MWs of solar generation and 5 MWs of battery storage of Saratoga and 20 MWs of solar generation of Ursa. If approved, our share of the cost of Ursa is estimated to be approximately $45 million, with construction expected to be completed in 2027. If approved, our share of the cost of Saratoga is estimated to be approximately $45 million, with construction expected to be completed in 2028.
•In September 2024, we, along with WE and an unaffiliated utility, filed a request with the PSCW to acquire and construct Badger Hollow Wind and to acquire Whitetail, two utility-scale wind-powered electric generating facilities. If approved, Badger Hollow Wind will be located in Iowa and Grant counties, Wisconsin and Whitetail will be located in Grant County, Wisconsin. Once fully constructed, we will own 11 MWs of wind generation of Badger Hollow Wind and 7 MWs of wind generation of Whitetail. If approved, our share of the cost of Badger Hollow Wind is estimated to be $36 million, with construction expected to be completed in 2027. If approved, our share of the cost of Whitetail is estimated to be approximately $22 million, with construction expected to be completed in 2027.
•In October 2024, we, along with WE and an unaffiliated utility, filed a request with the PSCW to acquire and construct Good Oak and Gristmill, two utility-scale solar electric generating facilities. If approved, both Good Oak and Gristmill will be located in Columbia County, Wisconsin. Once fully constructed, we will own 10 MWs of solar generation of Good Oak and 7 MWs of solar generation of Gristmill. If approved, our share of the cost of Good Oak is estimated to be $22 million and the cost of Gristmill is estimated to be approximately $14 million, with construction for both projects expected to be completed in 2028.
The construction of additional LNG facilities in Wisconsin has been proposed as part of WEC Energy Group's capital plan, which includes us. The facilities would provide approximately four Bcf of natural gas supply at an estimated cost of $940 million (of which our portion is expected to be approximately two Bcf) and are expected to reduce the likelihood of constraints on our natural gas distribution system during the highest demand days of winter.
As part of WEC Energy Group's capital plan, we, along with WE, plan to add natural gas-fired RICE units that would be capable of producing approximately 114 MWs at an estimated cost of $250 million.
In connection with several investigations it conducted, the DOC set duties on solar panels and cells imported from four southeast Asian countries. See Factors Affecting Results, Liquidity, and Capital Resources - Regulatory, Legislative, and Legal Matters - United States Department of Commerce Complaints and Factors Affecting Results, Liquidity, and Capital Resources - Regulatory, Legislative, and Legal Matters - Uyghur Forced Labor Prevention Act for information on the potential impacts to our solar projects as a result of the duties set by the DOC and related USITC and DOC investigations, and CBP actions related to solar panels, respectively. The expected in-service dates and costs identified above already reflect some of these impacts.
2024 Form 10-K 43
Wisconsin Public Service Corporation
Long-Term Debt
A significant amount of cash is required to retire and pay interest on our long-term debt obligations. See Note 14, Long-Term Debt, for more information on our outstanding long-term debt, including a schedule of our long-term debt maturities over the next five years. The following table summarizes our required interest payments on long-term debt as of December 31, 2024:
Interest Payments Due by Period
(in millions) Total Less Than 1 Year 1-3 Years 3-5 Years More Than 5 Years
Interest payments due on long-term debt $ 1,387.2 $ 93.4 $ 157.5 $ 153.1 $ 983.2
Common Stock Dividends
During the years ended December 31, 2024, 2023, and 2022, we paid common stock dividends of $170.0 million, $255.0 million, and $120.0 million, respectively, to the sole holder of our common stock, Integrys. Any payment of future dividends is subject to approval by our Board of Directors and is dependent upon future earnings, capital requirements, and financial and other business conditions. In addition, various financing arrangements and regulatory requirements impose certain restrictions on our ability to transfer funds to Integrys in the form of cash dividends, loans, or advances. We do not believe that these restrictions will materially affect our operations or limit any dividend payments in the foreseeable future. See Note 11, Common Equity for more information related to these restrictions and our other common stock matters.
Other Significant Cash Requirements
Our utility operations have purchase obligations under various contracts for the procurement of fuel, power, and gas supply, as well as the related storage and transportation. These costs are a significant component of funding our ongoing operations. See Note 21, Commitments and Contingencies, for more information, including our minimum future commitments related to these purchase obligations.
In addition to our energy-related purchase obligations, we have commitments for other costs incurred in the normal course of business, including costs related to information technology services, meter reading services, maintenance and other service agreements for certain generating facilities, and various engineering agreements. Our estimated future cash requirements related to these purchase obligations, excluding energy-related obligations, are reflected below.
Payments Due by Period
(in millions) Total Less Than 1 Year 1-3 Years 3-5 Years More Than 5 Years
Purchase orders $ 28.0 $ 12.5 $ 11.5 $ 4.0 $ -
We have various finance and operating lease obligations. Our finance lease obligations primarily relate to land leases for our renewable generation projects. See Note 15, Leases, for more information, including an analysis of our minimum lease payments due in future years.
We make contributions to our pension and OPEB plans based upon various factors affecting us, including our liquidity position and tax law changes. See Note 19, Employee Benefits, for our expected contributions in 2025 and our expected pension and OPEB payments for the next 10 years. We expect the majority of these future pension and OPEB payments to be paid from our outside trusts. See Sources of Cash-Investments in Outside Trusts below for more information.
In addition to the above, our balance sheet at December 31, 2024 included various other liabilities that, due to the nature of the liabilities, the amount and timing of future payments cannot be determined with certainty. These liabilities include AROs, liabilities for the remediation of manufactured gas plant sites, and liabilities related to the accounting treatment for uncertainty in income taxes. For additional information on these liabilities, see Note 9, Asset Retirement Obligations, Note 16, Income Taxes, and Note 21, Commitments and Contingencies, respectively.
Off-Balance Sheet Arrangements
We are a party to various financial instruments with off-balance sheet risk as a part of our normal course of business, including financial guarantees and letters of credit that support construction projects, commodity contracts, and other payment obligations.
2024 Form 10-K 44
Wisconsin Public Service Corporation
We believe that these agreements do not have, and are not reasonably likely to have, a current or future material effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures, or capital resources. See Note 1(q), Guarantees, and Note 13, Short-Term Debt and Lines of Credit, for more information.
Sources of Cash
Liquidity
We anticipate meeting our short-term and long-term cash requirements to operate our business and implement our corporate strategy through internal generation of cash from operations, equity contributions from our parent, and access to the capital markets, which allows us to obtain external short-term borrowings, including commercial paper, and intermediate or long-term debt securities. Cash generated from operations is primarily driven by sales of electricity and natural gas to our utility customers, reduced by costs of operations. Our access to the capital markets is critical to our overall strategic plan and allows us to supplement cash flows from operations with external borrowings to manage seasonal variations, working capital needs, commodity price fluctuations, unplanned expenses, and unanticipated events.
We maintain a bank back-up credit facility, which provides liquidity support for our obligations with respect to commercial paper and for general corporate purposes. We review our bank back-up credit facility needs on an ongoing basis and expect to be able to maintain adequate credit facilities to support our operations.
The amount, type, and timing of any financings in 2025, as well as in subsequent years, will be contingent on investment opportunities and our cash requirements and will depend upon prevailing market conditions, regulatory approvals, and other factors. We plan to maintain a capital structure consistent with that approved by the PSCW. For more information on our approved capital structure, see Item 1. Business - D. Regulation.
The issuance of our securities is subject to the approval of the PSCW. Additionally, with respect to the public offering of securities, we file registration statements with the SEC under the Securities Act of 1933, as amended (1933 Act). The amounts of securities authorized by the PSCW, as well as the securities registered under the 1933 Act, are closely monitored and appropriate filings are made to ensure flexibility in the capital markets.
At December 31, 2024, our current liabilities exceeded our current assets by $142.4 million. We do not expect this to have any impact on our liquidity as we currently believe that our cash and cash equivalents, our available capacity under our existing revolving credit facility, cash generated from ongoing operations, and access to the capital markets are adequate to meet our short-term and long-term cash requirements.
See Note 13, Short-Term Debt and Lines of Credit, and Note 14, Long-Term Debt, for more information about our commercial paper, credit facility, and debt securities.
Investments in Outside Trusts
We maintain investments in outside trusts to fund the obligation to provide pension and certain OPEB benefits to current and future retirees. As of December 31, 2024, these trusts had investments of approximately $1.0 billion, consisting of fixed income and equity securities, that are subject to the volatility of the stock market and interest rates. The performance of existing plan assets, long-term discount rates, changes in assumptions, and other factors could affect our future contributions to the plans, our financial position if our accumulated benefit obligation exceeds the fair value of the plan assets, and future results of operations related to changes in pension and OPEB expense and the assumed rate of return. For additional information, see Note 19, Employee Benefits.
Debt Covenants
Our credit facility contains financial covenants that we must satisfy, including a debt to capitalization ratio. At December 31, 2024, we were in compliance with all such covenants. We expect to be in compliance with all such debt covenants for the foreseeable future. See Note 13, Short-Term Debt and Lines of Credit, and Note 14, Long-Term Debt, for more information.
2024 Form 10-K 45
Wisconsin Public Service Corporation
Credit Rating Risk
Cash collateral postings and prepayments made with external parties, including postings related to exchange-traded contracts, and cash collateral posted by external parties were immaterial as of December 31, 2024. From time to time, we may enter into commodity contracts that could require collateral or a termination payment in the event of a credit rating change to below BBB- at S&P Global Ratings, a division of S&P Global Inc., and/or Baa3 at Moody’s Investors Service, Inc. We also have other commodity contracts that, in the event of a credit rating downgrade, could result in a reduction of our unsecured credit granted by counterparties.
In addition, access to capital markets at a reasonable cost is determined in large part by credit quality. Any credit ratings downgrade could impact our ability to access capital markets.
Subject to other factors affecting the credit markets as a whole, we believe our current ratings should provide a significant degree of flexibility in obtaining funds on competitive terms. However, these security ratings reflect the views of the rating agency only. An explanation of the significance of these ratings may be obtained from the rating agency. Such ratings are not a recommendation to buy, sell, or hold securities. Any rating can be revised upward or downward or withdrawn at any time by a rating agency.
FACTORS AFFECTING RESULTS, LIQUIDITY, AND CAPITAL RESOURCES
Competitive Markets
Electric Utility Industry
The FERC supports large RTOs, which directly impacts the structure of the wholesale electric market. Due to the FERC's support of RTOs, MISO uses the MISO Energy Markets to carry out its operations, including the use of LMPs to value electric transmission congestion and losses. Increased competition in the retail and wholesale markets, which may result from restructuring efforts, could have a significant and adverse financial impact on us.
Electric utility revenues in Wisconsin are regulated by the PSCW. The PSCW continues to maintain the position that the question of whether to implement electric retail competition in Wisconsin should ultimately be decided by the Wisconsin legislature. No such legislation has been introduced in Wisconsin to date, and it is uncertain when, if at all, retail choice might be implemented in Wisconsin.
Natural Gas Utility Industry
We offer both natural gas transportation service and interruptible natural gas sales to enable customers to better manage their energy costs. Customers continue to switch between firm system supply, interruptible system supply, and transportation service each year as the economics and service options change.
Due to the PSCW's previous proceedings on natural gas industry regulation in a competitive environment, the PSCW currently provides all Wisconsin customer classes with competitive markets the option to choose a third-party natural gas supplier. All of our Wisconsin non-residential customer classes have competitive market choices and, therefore, can purchase natural gas directly from either a third-party supplier or us. Since third-party suppliers can be used in Wisconsin, the PSCW has also adopted standards for transactions between a utility and its natural gas marketing affiliates.
We offer natural gas transportation services to our customers that elect to purchase natural gas directly from a third-party supplier. Since these transportation customers continue to use our distribution systems to transport natural gas to their facilities, we earn distribution revenues from them. As such, the loss of revenue associated with the cost of natural gas that our transportation customers purchase from third-party suppliers has little impact on our net income, as it is substantially offset by an equal reduction to natural gas costs.
We are currently unable to predict the impact, if any, of potential future industry restructuring on our results of operations or financial position.
2024 Form 10-K 46
Wisconsin Public Service Corporation
Regulatory, Legislative, and Legal Matters
Regulatory Recovery
We account for our regulated operations in accordance with accounting guidance under the Regulated Operations Topic of the FASB ASC. Our rates are determined by the PSCW and the FERC. See Item 1. Business - D. Regulation for more information on these commissions. See Note 23, Regulatory Environment, for additional information regarding recent rate proceedings and orders.
Regulated entities are allowed to defer certain costs that would otherwise be charged to expense if the regulated entity believes the recovery of those costs is probable. We record regulatory assets pursuant to generic and/or specific orders issued by our regulators. Recovery of the deferred costs in future rates is subject to the review and approval by our regulators. We assume the risks and benefits of ultimate recovery of these items in future rates. If the recovery of the deferred costs is not approved by our regulators, the costs would be charged to income in the current period. Regulators can impose liabilities on a prospective basis for amounts previously collected from customers and for amounts that are expected to be refunded to customers. We record these items as regulatory liabilities. See Note 6, Regulatory Assets and Liabilities, for more information on our regulatory assets and liabilities.
Petitions Before PSCW Regarding Third-Party Financed Distributed Energy Resources
In May 2022, a petition was filed with the PSCW requesting a declaratory ruling that the owner of a third-party financed DER is not a "public utility" as defined under Wisconsin law and, therefore, is not subject to the PSCW’s jurisdiction under any statute or rule regulating public utilities. The party that filed the petition provides financing to its customers for installation of DERs (including solar panels and energy storage) on the customer’s property. A DER is connected to the host customer’s utility meter and is used for the customer’s energy needs. It may also be connected to the grid for distribution.
In December 2022, the PSCW granted the petitioner’s request for a declaratory ruling in part, finding that the owner of the third-party financed DER at issue in the petitioner’s brief is not a public utility under Wisconsin law, but declining to issue the petitioner’s request for a broader declaratory ruling that the petitioner would not be regulated as a "public utility".
Upon appeal, in April 2024, the Dane County Circuit Court reversed the PSCW’s decision, finding that the PSCW erroneously interpreted the definition of "public utility," and the evidence did not support its determination that the lease at issue in the petition did not involve the sale of electricity to the "public" under Wisconsin law. The case was remanded to the PSCW for further review. Although the PSCW issued an order in June 2024 to reopen the docket to consider modifications, the project lease originally at issue was no longer going forward, and so in October 2024 the PSCW issued an order declining to issue any declaratory ruling.
Meanwhile, in June 2024, the party that filed the May 2022 PSCW petition appealed the Dane County Circuit Court’s April 2024 decision to the Wisconsin Court of Appeals. That appeal was in briefing when the PSCW issued its October 2024 order, which left the Court of Appeals with no agency decision to review. Based on this and the fact that the underlying project was no longer going forward, a motion to dismiss the appeal was granted by the Court of Appeals in February 2025. At this time we do not expect any material impact on our business operations.
Uyghur Forced Labor Prevention Act
The CBP issued a WRO in June 2021, applicable to certain silica-based products originating from the Xinjiang Uyghur Autonomous Region of China (Xinjiang), such as polysilicon, included in the manufacturing of solar panels. In June 2022, the WRO was superseded by the implementation of the UFLPA. The UFLPA establishes a rebuttable presumption that any imports wholly or partially manufactured in Xinjiang are prohibited from entering the United States. While our suppliers have been able to provide the CBP sufficient documentation to meet WRO compliance requirements, and we expect the same will be true for UFLPA purposes, we cannot currently predict what, if any, long-term impact the UFLPA will have on the overall supply of solar panels into the United States and whether we will experience any further impacts to the timing and cost of our solar projects included in WEC Energy Group's long-term capital plan.
In January 2025, the Department of Homeland Security announced the addition of several more Chinese businesses to the UFLPA, including five solar supply chain providers. We are working to avoid doing business with these companies and remain in compliance with the UFLPA.
2024 Form 10-K 47
Wisconsin Public Service Corporation
United States Department of Commerce Complaints
The solar panel industry continues to experience uncertainty resulting from AD and CVD investigations involving four southeast Asian countries including Malaysia, Vietnam, Thailand, and Cambodia.
In August 2023, the DOC issued a final decision regarding an AD/CVD petition filed by a California-based company alleging that Chinese manufacturers were shifting products to the four southeast Asian countries to avoid tariffs required on products imported from China and requesting that the DOC conduct a country-wide inquiry into each country. In its final decision, the DOC determined that circumvention was occurring in each of the four Southeast Asian countries noted above. Duties began to be applied to certain imports of solar cells from Malaysia, Vietnam, Thailand and Cambodia after expiration of the 24-month tariff moratorium on June 6, 2024. In addition, in response to its findings, the DOC promulgated new regulations that imposed enhanced duties in certain circumstances, including when the USITC determines there is a reasonable indication the domestic solar industry is materially or potentially injured because of imported products that violate certain fair trade laws.
In April 2024, a coalition of several U.S. producers of solar panels filed a petition with the DOC requesting new tariffs on imports from the same four Southeast Asian countries. The group alleged that some Chinese companies had moved their solar operations to avoid penalties implemented after the expiration of the moratorium. In May 2024, in response to the petition, the DOC initiated a new AD/CVD investigation of solar panels from the four southeast Asian countries.
In April 2024, the USITC began a preliminary investigation and, in June 2024, issued a preliminary determination that there is a reasonable indication imports of solar panels from the four Southeast Asian countries have caused injury to the U.S. solar industry. Based on the USITC’s preliminary decision, the DOC began an investigation and, in October and November 2024, announced preliminary affirmative determinations in its CVD and AD investigations, respectively, and set preliminary duties on imports from the four southeast Asian countries. The DOC and USITC are expected to make final determinations in the second quarter of 2025, which could result in enhanced duties, including retroactive duties in certain circumstances.
The Biden Administration invoked the Defense Production Act to accelerate the production of solar panels in the U.S.; however, final determinations by the DOC and/or USITC may have an adverse impact on the solar industry overall. Additionally, there is uncertainty with respect to how WROs applied to panels under previous complaints would be affected.
As a result of these investigations, the solar industry overall has experienced higher costs of materials as well as delays. Some of these impacts have already been reflected in the estimated cost and in-service dates for certain of our solar projects. We are continuing to assess the potential impact from the preliminary determinations on our business and results of operations.
Infrastructure Investment and Jobs Act and Inflation Reduction Act
In November 2021, former President Biden signed into law the Infrastructure Investment and Jobs Act, which provides for approximately $1.2 trillion of federal spending over a five year period, including approximately $85 billion for investments in power, utilities, and renewables infrastructure across the United States. We believe that funding from this Act would support the work we are doing to reduce GHG emissions, increase EV charging, and strengthen and protect the energy grid. Funding in the Act could also help to expand emerging technologies, like hydrogen and carbon management, as we continue the transition to a clean energy future to the benefit of our customers, the communities we serve, and our company.
In August 2022, former President Biden signed into law the IRA, which provides for $258 billion in energy-related provisions over a 10-year period. The provisions of the IRA are intended to, among other things, lower gasoline and electricity prices, incentivize domestic clean energy investment, manufacturing, and production, and promote reductions in carbon emissions. We believe that we and our customers can benefit from the IRA’s provisions that extend tax benefits for renewable technologies, increase or restore higher rates for PTCs, add an option to claim PTCs for solar projects, expand qualified ITC facilities to include standalone energy storage, and its provision to allow companies to transfer tax credits generated from renewable projects.
Under the IRA transferability option, WEC Energy Group entered into an agreement in 2024 to sell substantially all of our 2024 PTCs to a third party. Additionally, in October 2024, WEC Energy Group entered into an agreement to sell the majority of our 2025 PTCs to a third party. See Note 1(n), Income Taxes, for more information about the impact of these sales during 2024. The IRA also implements a 15% corporate alternative minimum tax and a 1% excise tax on stock repurchases. Although significant regulatory guidance is expected on the tax provisions in the IRA, we currently believe the provisions on alternative minimum tax and stock repurchases will not have a material impact on us. Overall, we believe the IRA will help reduce our cost of investing in projects that
2024 Form 10-K 48
Wisconsin Public Service Corporation
will support our commitment to reduce emissions and provide customers affordable, reliable, and clean energy over the longer term.
In January 2025, pursuant to an executive order issued by the new presidential administration, disbursement of funds under these two Acts was paused until agency heads can determine whether grants, loans contracts, and other disbursements are consistent with the new administration's energy policy. Agency heads must consult with the Office of Management and Budget and the National Economic Council prior to any funding being disbursed. The new policy encourages use of domestic energy sources including oil, natural gas, coal, hydropower, biofuels, critical minerals, and nuclear, promotes consumer choice of goods and appliances, aims to boost American workers and businesses, eliminates the EV mandate, and limits regulations that apply to the energy industry. The executive order did not impact the IRA's provisions for tax credits and the transferability option.
Environmental Matters
See Note 21, Commitments and Contingencies, for a discussion of certain environmental matters affecting us, including rules and regulations relating to air quality, water quality, and land quality.
Market Risks and Other Significant Risks
We are exposed to market and other significant risks as a result of the nature of our businesses and the environments in which those businesses operate. These include, but are not limited to, the risks described below. In addition, there is continuing uncertainty over the impact that the ongoing regional and international conflicts, including those in Ukraine, Israel and in other parts of the Middle East, will have on the global economy, supply chains, and fuel prices.
Commodity Costs
In the normal course of providing energy, we are subject to market fluctuations in the costs of coal, natural gas, purchased power, and fuel oil used in the delivery of coal. We manage our fuel and natural gas supply costs through a portfolio of short and long-term procurement contracts with various suppliers for the purchase of coal, natural gas, and fuel oil. In addition, we manage the risk of price volatility through natural gas and electric hedging programs.
Embedded within our rates are amounts to recover fuel, natural gas, and purchased power costs. We have recovery mechanisms in place that generally allow us to recover or refund all or a portion of the changes in prudently incurred fuel, natural gas, and purchased power costs from rate case-approved amounts. See Item 1. Business - D. Regulation for more information on these mechanisms.
Higher commodity costs can increase our working capital requirements, result in higher gross receipts taxes, and lead to increased energy efficiency investments by our customers to reduce utility usage and/or fuel substitution. Higher commodity costs combined with slower economic conditions also expose us to greater risks of accounts receivable write-offs as more customers are unable to pay their bills. See Note 5, Credit Losses, for more information on our mechanism that allows for cost recovery or refund of uncollectible expense.
Weather
Our utility rates are based upon estimated normal temperatures. Our electric utility margins are unfavorably sensitive to below normal temperatures during the summer cooling season and, to some extent, to above normal temperatures during the winter heating season. Our natural gas utility margins are unfavorably sensitive to above normal temperatures during the winter heating season. The fixed charge included in our natural gas rates helps to mitigate the impacts of weather. A summary of actual weather information in our service territory during 2024, 2023, and 2022, as measured by degree days, can be found in Results of Operations.
Our operations, primarily our electric operations, can be negatively impacted from storms. High wind conditions, lightning, hail, and flooding from storms can result in downed wires and poles, as well as damage to wind and solar generation facilities and other operating equipment. This can result in us incurring significant restoration costs and lost revenue to our customers. Our rates include a fixed amount for expected storm restoration costs. To the extent actual storm restoration costs are above what is included in these rates, our earnings are negatively impacted and it becomes more difficult to achieve our authorized ROE.
2024 Form 10-K 49
Wisconsin Public Service Corporation
Interest Rates
We are exposed to interest rate risk resulting from our short-term borrowings and projected near-term debt financing needs. We manage exposure to interest rate risk by limiting the amount of our variable rate obligations and continually monitoring the effects of market changes on interest rates. When it is advantageous to do so, we enter into long-term fixed rate debt.
Based on our variable rate debt outstanding at December 31, 2024 and 2023, a hypothetical increase in market interest rates of one percentage point would have increased annual interest expense by $0.6 million and $3.1 million in 2024 and 2023, respectively. This sensitivity analysis was performed assuming a constant level of variable rate debt during the period and an immediate increase in interest rates, with no other changes for the remainder of the period.
Marketable Securities Return
We use various trusts to fund our pension and OPEB obligations. These trusts invest in debt and equity securities. Changes in the market prices of these assets can affect future pension and OPEB expenses. Additionally, future contributions can also be affected by the investment returns on trust fund assets. The financial risks associated with investment returns are mitigated through the requirement that we implement escrow accounting treatment for pension and OPEB costs in 2023 through 2026, as required by the December 2022 and December 2024 rate orders issued by the PSCW. As a result, we defer as a regulatory asset or liability, the difference between actual pension and OPEB costs and those included in rates until recovery or refund is authorized in a future rate proceeding.
The fair value of our trust fund assets and expected long-term returns were approximately:
(in millions) As of December 31, 2024 Expected Return on Assets in 2025
Pension trust funds $ 713.6 6.75 %
OPEB trust funds $ 281.1 6.50 %
Fiduciary oversight of the pension and OPEB trust fund investments is the responsibility of an Investment Trust Policy Committee. The Committee works with external actuaries and investment consultants on an ongoing basis to establish and monitor investment strategies and target asset allocations. Forecasted cash flows for plan liabilities are regularly updated based on annual valuation results. Target asset allocations are determined utilizing projected benefit payment cash flows and risk analyses of appropriate investments. The targeted asset allocations are intended to reduce risk, provide long-term financial stability for the plans and maintain funded levels which meet long-term plan obligations while preserving sufficient liquidity for near-term benefit payments. Investment strategies utilize a wide diversification of asset types and qualified external investment managers.
WEC Energy Group consults with its investment advisors on an annual basis to help it forecast expected long-term returns on plan assets by reviewing actual historical returns and calculating expected total trust returns using the weighted-average of long-term market returns for each of the major target asset categories utilized in the funds.
Economic Conditions
Our service territories are within the state of Wisconsin. As such, we are exposed to market risks in the regional Midwest economy. In addition, any economic downturn or disruption of national or international markets could adversely affect the financial condition of our customers and demand for their products, which could affect their demand for our products.
Inflation and Supply Chain Disruptions
We continue to monitor the impact of inflation and supply chain disruptions. We monitor the costs of medical plans, fuel, transmission access, construction costs, regulatory and environmental compliance costs, and other costs in order to minimize inflationary effects in future years, to the extent possible, through pricing strategies, productivity improvements, and cost reductions. We monitor the global supply chain, and related disruptions, in order to ensure we are able to procure the materials and other resources necessary to both maintain our energy services in a safe and reliable manner and to grow our infrastructure in
2024 Form 10-K 50
Wisconsin Public Service Corporation
accordance with WEC Energy Group's capital plan, which includes us. For additional information concerning risks related to inflation and supply chain disruptions, see the four risk factors below.
•Item 1A. Risk Factors - Risks Related to the Operation of Our Business - Public health crises, including epidemics and pandemics, could adversely affect our business functions, financial condition, liquidity, and results of operations.
•Item 1A. Risk Factors - Risks Related to the Operation of Our Business - Our operations and corporate strategy may be adversely affected by supply chain disruptions and inflation.
•Item 1A. Risk Factors - Risks Related to the Operation of Our Business - We are actively involved with multiple significant capital projects, which are subject to a number of risks and uncertainties that could adversely affect project costs and completion of construction projects.
•Item 1A. Risk Factors - Risks Related to Economic and Market Volatility - The fluctuation in demand for certain commodities and their respective prices could negatively impact our operations.
For additional information concerning risk factors, including market risks, see the Cautionary Statement Regarding Forward-Looking Information at the beginning of this report and Item 1A. Risk Factors.
Critical Accounting Policies and Estimates
The preparation of financial statements in compliance with GAAP requires the application of accounting policies, as well as the use of estimates, assumptions, and judgments that could have a material impact on our financial statements and related disclosures. Judgments regarding future events may include the likelihood of success of particular projects, legal and regulatory challenges, and anticipated recovery of costs. Actual results may differ significantly from estimated amounts based on varying assumptions.
Our significant accounting policies are described in Note 1, Summary of Significant Accounting Policies. The following is a list of accounting policies and estimates that require management's most difficult, subjective, or complex judgments and may change in subsequent periods.
Regulatory Accounting
Our utility operations follow the guidance under the Regulated Operations Topic of the FASB ASC (Topic 980). Our financial statements reflect the effects of the ratemaking principles followed by the jurisdictions regulating us. Certain items that would otherwise be immediately recognized as revenues and expenses are deferred as regulatory assets and regulatory liabilities for future recovery or refund to customers, as authorized by our regulators.
Future recovery of regulatory assets, including the timeliness of recovery and our ability to earn a reasonable return, is not assured and is generally subject to review by regulators in rate proceedings for matters such as prudence and reasonableness. Once approved, the regulatory assets and liabilities are amortized into earnings over the rate recovery or refund period. If recovery or refund of costs is not approved or is no longer considered probable, these regulatory assets or liabilities are recognized in current period earnings. Management regularly assesses whether these regulatory assets and liabilities are probable of future recovery or refund by considering factors such as changes in the regulatory environment, earnings from our electric and natural gas utility operations, rate orders issued by our regulators, historical decisions by our regulators regarding regulatory assets and liabilities, and the status of any pending or potential deregulation legislation.
The application of the Regulated Operations Topic of the FASB ASC would be discontinued if all or a separable portion of our utility operations no longer met the criteria for application. Our regulatory assets and liabilities would be written off to income as an unusual or infrequently occurring item in the period in which discontinuation occurred. See Note 6, Regulatory Assets and Liabilities, for more information on our regulatory assets and liabilities.
Goodwill
We completed our annual goodwill impairment test for our utility reporting unit that carried $36.4 million of goodwill as of July 1, 2024. No impairment was recorded as a result of this test. The fair value calculated in step one of the test was greater than its
2024 Form 10-K 51
Wisconsin Public Service Corporation
carrying value. The fair value of our reporting unit was calculated using a combination of the income approach and the market approach.
For the income approach, we used internal forecasts to project cash flows. Any forecast contains a degree of uncertainty, and changes in these cash flows could significantly increase or decrease the calculated fair value of a reporting unit. Since our reporting unit is regulated, a fair recovery of and return on costs prudently incurred to serve customers is assumed. An unfavorable outcome in a rate case could cause the fair value of our reporting unit to decrease.
Key assumptions used in the income approach include ROE, the long-term growth rate used to determine the terminal value at the end of the discrete forecast period, and the discount rate. The discount rate is applied to estimated future cash flows and is one of the most significant assumptions used to determine fair value under the income approach. As interest rates rise, the calculated fair value will decrease. The discount rate is based on the weighted-average cost of capital, taking into account both the after-tax cost of debt and cost of equity. The terminal year ROE is driven by our current allowed ROE. The terminal growth rate is based primarily on a combination of historical and forecasted statistics for real gross domestic product and personal income for our service area.
For the market approach, we used a higher weighting for the guideline public company method than the guideline merged and acquired company method due to a low number of mergers and acquisitions in recent years. The guideline public company method uses financial metrics from similar utility companies to determine fair value. The guideline merged and acquired company method calculates fair value by analyzing the actual prices paid for recent mergers and acquisitions in the industry. We applied multiples derived from these two methods to the appropriate operating metrics for our reporting unit to determine fair value.
The underlying assumptions and estimates used in the impairment test were made as of a point in time. Subsequent changes in these assumptions and estimates could change the result of the test.
At July 1, 2024, the fair value of our reporting unit exceeded its carrying value by over 50%. Based on this result, our reporting unit is not at risk of failing step one of the goodwill impairment test.
See Note 10, Goodwill and Intangible Assets, for more information.
Long-Lived Assets
In accordance with ASC 980-360, Regulated Operations - Property, Plant, and Equipment, we periodically assess the recoverability of certain long-lived assets when events or changes in circumstances indicate that the carrying amount of those long-lived assets may not be recoverable. Examples of events or changes in circumstances include, but are not limited to, a significant decrease in the market price, a significant change in use, a regulatory decision related to recovery of assets from customers, adverse legal factors or a change in business climate, operating or cash flow losses, or an expectation that the asset might be sold or abandoned. See Note 1(j), Asset Impairment, for our policy on accounting for abandonments and recently completed plant subject to disallowance.
Performing an impairment evaluation involves a significant degree of estimation and judgment by management in areas such as identifying circumstances that indicate an impairment may exist, identifying and grouping affected assets, and developing the undiscounted future cash flows. An impairment loss is measured as the excess of the carrying amount of the asset in comparison to the fair value of the asset. The fair value of the asset is assessed using various methods, including internally developed discounted cash flow analysis, expected recovery of regulated assets, and analysis from outside advisors.
See Note 7, Property, Plant, and Equipment, for more information on our generating units probable of being retired. See Note 6, Regulatory Assets and Liabilities, and Note 23, Regulatory Environment, for more information on our retired generating units, including various approvals we received from the FERC and the PSCW.
Pension and Other Postretirement Employee Benefits
The costs of providing non-contributory defined pension benefits and OPEB, described in Note 19, Employee Benefits, are dependent upon numerous factors resulting from actual plan experience and assumptions of future experience.
Pension and OPEB costs are impacted by actual employee demographics (including age, compensation levels, and employment periods), the level of contributions made to the plans, and earnings on plan assets. Pension and OPEB costs may also be significantly affected by changes in key actuarial assumptions, including anticipated rates of return on plan assets, mortality and discount rates,
2024 Form 10-K 52
Wisconsin Public Service Corporation
and expected health care cost trends. Changes made to the plan provisions may also impact current and future pension and OPEB costs.
Pension and OPEB plan assets are primarily made up of equity and fixed income investments. Fluctuations in actual equity and fixed income market returns, as well as changes in general interest rates, may result in increased or decreased benefit costs in future periods. Changes in benefit costs are mitigated through the requirement that we implement escrow accounting treatment for pension and OPEB costs in 2023 and 2024, as required by the December 2022 rate order issued by the PSCW. See Note 23, Regulatory Environment, for more information on our 2023 and 2024 rates.
The following table shows how a given change in certain actuarial assumptions would impact the projected benefit obligation and the reported net periodic pension cost (including amounts capitalized to our balance sheets). Each factor below reflects an evaluation of the change based on a change in that assumption only.
Actuarial Assumption
(in millions, except percentages)
Percentage-Point Change in Assumption Impact on Projected Benefit Obligation Impact on 2024
Pension Cost
Discount rate (0.5) $ 30.4 $ (0.6)
Discount rate 0.5 (28.4) 0.6
Rate of return on plan assets (0.5) N/A 3.8
Rate of return on plan assets 0.5 N/A (3.8)
The following table shows how a given change in certain actuarial assumptions would impact the accumulated OPEB obligation and the reported net periodic OPEB cost (including amounts capitalized to our balance sheets). Each factor below reflects an evaluation of the change based on a change in that assumption only.
Actuarial Assumption
(in millions, except percentages)
Percentage-Point Change in Assumption Impact on Postretirement
Benefit Obligation Impact on 2024 Postretirement
Benefit Cost
Discount rate (0.5) $ 6.9 $ -
Discount rate 0.5 (6.5) (0.7)
Health care cost trend rate (0.5) (5.3) (1.2)
Health care cost trend rate 0.5 6.0 0.6
Rate of return on plan assets (0.5) N/A 1.3
Rate of return on plan assets 0.5 N/A (1.3)
The discount rates are selected based on hypothetical bond portfolios consisting of noncallable, high-quality corporate bonds across the full maturity spectrum. From the hypothetical bond portfolios, a single rate is determined that equates the market value of the bonds purchased to the discounted value of the plans' expected future benefit payments.
We establish our expected return on assets based on consideration of historical and projected asset class returns, as well as the target allocations of the benefit trust portfolios. The assumed long-term rate of return on pension plan assets was 6.75% in 2024 and 2023, and 7.00% in 2022. The actual rate of return on pension plan assets, net of fees, was 4.28%, 10.43%, and (16.93)% in 2024, 2023, and 2022, respectively.
In selecting assumed health care cost trend rates, past performance and forecasts of health care costs are considered. For more information on health care cost trend rates and a table showing future payments that we expect to make for our pension and OPEB, see Note 19, Employee Benefits.
Unbilled Revenues
We record utility operating revenues when energy is delivered to our customers. However, the determination of energy sales to individual customers is based upon the reading of their meters, which occurs on a systematic basis throughout the month. At the end of each month, amounts of energy delivered to customers since the date of their last meter reading are estimated and corresponding unbilled revenues are calculated.
Unbilled revenues are estimated each month based upon actual generation and throughput volumes, recorded sales, estimated customer usage by class, weather factors, estimated line losses, and applicable customer rates. Energy demand for the unbilled period or changes in rate mix due to fluctuations in usage patterns of customer classes could impact the accuracy of the unbilled
2024 Form 10-K 53
Wisconsin Public Service Corporation
revenue estimate. Total unbilled utility revenues were $65.8 million and $64.1 million as of December 31, 2024 and 2023, respectively. The changes in unbilled revenues are primarily due to changes in the cost of natural gas, weather, and customer rates.
Income Tax Expense
Significant management judgment is required in determining our provision for income taxes, deferred income tax assets and liabilities, the liability for unrecognized tax benefits, and any valuation allowance recorded against deferred income tax assets. The assumptions involved are supported by historical data, reasonable projections, and interpretations of applicable tax laws and regulations across multiple taxing jurisdictions. Significant changes in these assumptions could have a material impact on our financial condition and results of operations. See Note 1(n), Income Taxes, and Note 16, Income Taxes, for a discussion of accounting for income taxes.
We are required to estimate income taxes for each of our applicable tax jurisdictions as part of the process of preparing financial statements. This process involves estimating current income tax liabilities together with assessing temporary differences resulting from differing treatment of items, such as depreciation, for income tax and accounting purposes. These differences result in deferred income tax assets and liabilities, which are included within our balance sheets. We also assess the likelihood that our deferred income tax assets will be recovered through future taxable income. To the extent we believe that realization is not likely, we establish a valuation allowance, which is offset by an adjustment to income tax expense in our income statements.
Uncertainty associated with the application of tax statutes and regulations, the outcomes of tax audits and appeals, changes in income tax law, enacted tax rates or amounts subject to income tax, and changes in the regulatory treatment of any tax reform benefits requires that judgments and estimates be made in the accrual process and in the calculation of effective tax rates. Only income tax benefits that meet the "more likely than not" recognition threshold may be recognized or continue to be recognized. Unrecognized tax benefits are re-evaluated quarterly and changes are recorded based on new information, including the issuance of relevant guidance by the courts or tax authorities and developments occurring in the examinations of our tax returns.
We expect our 2025 annual effective tax rate to be between 18% and 19%. Our effective tax rate calculations are revised every quarter based on the best available year-end tax assumptions, adjusted in the following year after returns are filed. Tax accrual estimates are trued-up to the actual amounts claimed on the tax returns and further adjusted after examinations by taxing authorities, as needed.

---

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
See Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Factors Affecting Results, Liquidity, and Capital Resources - Market Risks and Other Significant Risks, as well as Note 1(o), Fair Value Measurements, Note 1(p), Derivative Instruments, and Note 1(q), Guarantees, for information concerning potential market risks to which we are exposed.
2024 Form 10-K 54
Wisconsin Public Service Corporation

---

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
A. REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the shareholder and the Board of Directors of Wisconsin Public Service Corporation
Opinion on the Financial Statements
We have audited the accompanying balance sheets of Wisconsin Public Service Corporation (the "Company") as of December 31, 2024 and 2023, the related statements of income, equity, and cash flows for each of the three years in the period ended December 31, 2024, and the related notes and the schedule listed in the Index at Item 15 (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2024 and 2023, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2024, in conformity with accounting principles generally accepted in the United States of America.
Basis for Opinion
These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company's financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.
Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current-period audit of the financial statements that was communicated or required to be communicated to the audit committee and that (1) relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Regulatory Assets and Liabilities - Impact of rate regulation on financial statements - Refer to Notes 6 and 23 to the financial statements
Critical Audit Matter Description
The Company is subject to regulation by state and federal regulatory bodies (collectively the “Commissions”) which have jurisdiction with respect to the rates of electric and gas distribution. Management has determined the Company meets the requirements under accounting principles generally accepted in the United States of America to prepare its financial statements applying the Regulated Operations Topic of the Financial Accounting Standards Board’s Accounting Standard Codification.
2024 Form 10-K 55
Wisconsin Public Service Corporation
Rates are determined and approved in regulatory proceedings based on an analysis of the Company’s costs to provide utility service and a return on, and recovery of, the Company’s investment in the utility business. Current and future regulatory decisions can have an impact on the recovery of costs, the rate of return earned on investment, and the timing and amount of assets to be recovered through rates. The Commissions’ regulation of rates is premised on the full recovery of prudently incurred costs and a reasonable rate of return on invested capital. Certain items that would otherwise be immediately recognized as revenues and expenses are deferred as regulatory assets and regulatory liabilities for future recovery or refund to customers, as authorized by the Company’s regulators. While the Company has indicated it expects to recover costs from customers through regulated rates, there is a risk that the Commissions will not approve: (1) full recovery of the costs of providing utility service, (2) full recovery of all amounts invested in the utility business and a reasonable return on that investment or (3) timely recovery of costs incurred.
We identified the impact of rate regulation as a critical audit matter due to the significant judgments made by management to support its assertions about the impacted account balances and disclosures and the subjectivity involved in assessing the impact of future regulatory orders on the financial statements. Management judgments include assessing the likelihood of (1) recovery in future rates of incurred costs and/or (2) a refund to customers. Auditing these judgments required specialized knowledge of accounting for rate regulation and the rate setting process due to its inherent complexities.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to the impact of rate regulation on certain assets and liabilities included the following, among others:
•We tested the effectiveness of management’s controls over regulatory assets and liabilities, including management’s controls over the identification of costs recorded as regulatory assets and liabilities and the monitoring and evaluation of regulatory developments that may affect the likelihood of recovering costs in future rates.
•We inquired of Company management and independently obtained and read: (1) relevant regulatory orders issued by the Commissions for the Company, (2) Company filings with the Commissions, (3) filings made by intervenors and (4) other publicly available information to assess the likelihood of recovery in future rates or of a future reduction in rates based on precedents of the Commissions’ treatment of similar costs under similar circumstances. To assess completeness, we evaluated the information obtained and compared it to management’s recorded regulatory asset and liability balances.
•For regulatory matters in process, we inspected the Company’s filings with the Commissions and the filings with the Commissions by intervenors that may impact the Company’s future rates, for any evidence that might contradict management’s assertions.
•We evaluated management’s conclusions regarding the probability of recovery for regulatory assets or refund or future reduction in rates for regulatory liabilities not yet addressed in a regulatory order.
•We evaluated the Company’s disclosures related to the impacts of rate regulation, including the balances recorded and regulatory developments.
/s/ DELOITTE & TOUCHE LLP
Milwaukee, Wisconsin
February 21, 2025
We have served as the Company's auditor since 2002.
2024 Form 10-K 56
Wisconsin Public Service Corporation
B. INCOME STATEMENTS
Year Ended December 31
(in millions) 2024 2023 2022
Operating revenues $ 1,560.4 $ 1,681.4 $ 1,785.2
Operating expenses
Cost of sales 485.3 606.8 845.1
Other operation and maintenance 440.3 434.3 362.5
Depreciation and amortization 238.5 226.9 199.8
Property and revenue taxes 46.9 47.4 42.4
Total operating expenses 1,211.0 1,315.4 1,449.8
Operating income 349.4 366.0 335.4
Other income, net 50.1 45.9 42.3
Interest expense 95.0 89.0 70.5
Other expense (44.9) (43.1) (28.2)
Income before income taxes 304.5 322.9 307.2
Income tax expense 51.6 62.7 72.2
Net income $ 252.9 $ 260.2 $ 235.0
The accompanying Notes to Financial Statements are an integral part of these financial statements.
2024 Form 10-K 57
Wisconsin Public Service Corporation
C. BALANCE SHEETS
At December 31
(in millions, except share and per share amounts) 2024 2023
Assets
Current assets
Cash and cash equivalents $ 1.5 $ 1.4
Accounts receivable and unbilled revenues, net of reserves of $8.6 and $10.9, respectively
225.1 219.2
Accounts receivable from related parties 29.6 35.7
Materials, supplies, and inventories 167.1 171.1
Prepaid taxes 57.4 48.9
Other prepayments 8.2 6.5
Other 13.8 20.5
Current assets 502.7 503.3
Long-term assets
Property, plant, and equipment, net of accumulated depreciation and amortization of $2,190.8 and $2,033.4, respectively
6,139.2 5,801.4
Regulatory assets 449.7 360.6
Goodwill 36.4 36.4
Pension and OPEB assets 328.9 284.5
Other 38.8 44.9
Long-term assets 6,993.0 6,527.8
Total assets $ 7,495.7 $ 7,031.1
Liabilities and Equity
Current liabilities
Short-term debt $ 62.0 $ 310.3
Current portion of long-term debt 300.0 -
Accounts payable 118.9 118.5
Accounts payable to related parties 77.5 57.6
Customer credit balances 33.7 28.4
Other 53.0 65.2
Current liabilities 645.1 580.0
Long-term liabilities
Long-term debt 1,958.0 1,959.1
Finance lease obligations 65.7 49.0
Deferred income taxes 996.9 924.4
Deferred ITCs 68.2 71.9
Regulatory liabilities 696.3 672.0
Environmental remediation liabilities 77.3 85.3
AROs 191.2 56.7
Other 85.2 79.0
Long-term liabilities 4,138.8 3,897.4
Commitments and contingencies (Note 21)
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 1,857.2 1,782.0
Retained earnings 759.0 676.1
Common shareholder's equity 2,711.8 2,553.7
Total liabilities and equity $ 7,495.7 $ 7,031.1
The accompanying Notes to Financial Statements are an integral part of these financial statements.
2024 Form 10-K 58
Wisconsin Public Service Corporation
D. STATEMENTS OF CASH FLOWS
Year Ended December 31
(in millions) 2024 2023 2022
Operating activities
Net income $ 252.9 $ 260.2 $ 235.0
Reconciliation to cash provided by operating activities
Depreciation and amortization 238.5 226.9 199.8
Deferred income taxes and ITCs, net 52.5 44.9 70.0
Pension and OPEB income (8.0) (7.6) (25.3)
Net change in transmission regulatory asset and liability (13.4) 1.5 (21.6)
Change in -
Accounts receivable and unbilled revenues, net 6.2 47.8 (56.6)
Materials, supplies, and inventories 4.0 (1.8) (51.6)
Prepaid taxes (8.5) 9.5 (18.4)
Collateral on deposit 10.3 10.7 (20.3)
Other current assets (1.8) 2.0 (2.3)
Accounts payable (13.2) (45.4) 38.4
Other current liabilities 1.0 3.6 1.2
Other, net 12.4 23.4 (60.1)
Net cash provided by operating activities 532.9 575.7 288.2
Investing activities
Capital expenditures (493.8) (453.8) (433.8)
Acquisition of Whitewater - (38.0) -
Acquisition of Red Barn (2.1) (143.8) -
Proceeds from cash surrender value of life insurance - - 4.4
Reimbursement for ATC's construction costs 0.4 0.1 10.0
Other, net 8.6 (2.5) 0.4
Net cash used in investing activities (486.9) (638.0) (419.0)
Financing activities
Issuance of long-term debt 299.8 - 300.0
Change in short-term debt (248.3) 115.4 (136.1)
Payment of dividends to parent (170.0) (255.0) (120.0)
Equity contribution from parent 75.0 165.0 125.0
Other, net (2.4) (0.2) (2.0)
Net cash provided by (used in) financing activities (45.9) 25.2 166.9
Net change in cash, cash equivalents, and restricted cash 0.1 (37.1) 36.1
Cash, cash equivalents, and restricted cash at beginning of year 1.4 38.5 2.4
Cash, cash equivalents, and restricted cash at end of year $ 1.5 $ 1.4 $ 38.5
The accompanying Notes to Financial Statements are an integral part of these financial statements.
2024 Form 10-K 59
Wisconsin Public Service Corporation
E. STATEMENTS OF EQUITY
(in millions) Common
Stock Additional
Paid In
Capital Retained
Earnings Total Common Shareholder's Equity
Balance at December 31, 2021 $ 95.6 $ 1,491.5 $ 555.9 $ 2,143.0
Net income - - 235.0 235.0
Equity contribution from parent - 125.0 - 125.0
Payment of dividends to parent - - (120.0) (120.0)
Stock-based compensation and other - 0.3 - 0.3
Balance at December 31, 2022 $ 95.6 $ 1,616.8 $ 670.9 $ 2,383.3
Net income - - 260.2 260.2
Equity contribution from parent - 165.0 - 165.0
Payment of dividends to parent - - (255.0) (255.0)
Stock-based compensation and other - 0.2 - 0.2
Balance at December 31, 2023 $ 95.6 $ 1,782.0 $ 676.1 $ 2,553.7
Net income - - 252.9 252.9
Equity contribution from parent - 75.0 - 75.0
Payment of dividends to parent - - (170.0) (170.0)
Stock-based compensation and other - 0.2 - 0.2
Balance at December 31, 2024 $ 95.6 $ 1,857.2 $ 759.0 $ 2,711.8
The accompanying Notes to Financial Statements are an integral part of these financial statements.
2024 Form 10-K 60
Wisconsin Public Service Corporation
F. NOTES TO FINANCIAL STATEMENTS
NOTE 1-SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
(a) Nature of Operations-We are an electric and natural gas utility company that serves electric and natural gas customers in northeastern Wisconsin. We are subject to the jurisdiction of, and regulation by, the PSCW, which has general supervisory and regulatory powers over virtually all phases of the public utility industry in Wisconsin. In addition, we are subject to the jurisdiction of the FERC, which regulates our natural gas pipelines and wholesale electric rates. We are an indirect, wholly owned subsidiary of WEC Energy Group.
As used in these notes, the term "financial statements" includes the income statements, balance sheets, statements of cash flows, and statements of equity, unless otherwise noted.
These financial statements reflect our proportionate interests in certain jointly owned utility facilities. See Note 8, Jointly Owned Utility Facilities, for more information. 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.
(b) Basis of Presentation-We prepare our financial statements in conformity with GAAP. We make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results may differ from these estimates.
(c) Cash and Cash Equivalents-Cash and cash equivalents include marketable debt securities with an original maturity of three months or less.
(d) Operating Revenues-The following discussion includes our significant accounting policies related to operating revenues. For additional required disclosures on disaggregation of operating revenues, see Note 4, Operating Revenues.
Revenues from Contracts with Customers
Electric Utility Operating Revenues
Electricity sales to residential and commercial and industrial customers are generally accomplished through requirements contracts, which provide for the delivery of as much electricity as the customer needs. These contracts represent discrete deliveries of electricity and consist of one distinct performance obligation satisfied over time, as the electricity is delivered and consumed by the customer simultaneously. For our residential and commercial and industrial customers, our performance obligation is bundled to consist of both the sale and the delivery of the electric commodity.
The transaction price of the performance obligations for residential and commercial and industrial customers is valued using the rates, charges, terms, and conditions of service included in our tariffs, which have been approved by the PSCW. These rates often have a fixed component customer charge and a usage-based variable component charge. We recognize revenue for the fixed component customer charge monthly using a time-based output method. We recognize revenue for the usage-based variable component charge using an output method based on the quantity of electricity delivered each month. Our retail electric rates include base amounts for fuel and purchased power costs, which also impact our revenues. The electric fuel rules set by the PSCW allow us to defer, for subsequent rate recovery or refund, under- or over-collections of actual fuel and purchased power costs beyond a 2% price variance from the costs included in the rates charged to customers. We monitor the deferral of under-collected costs to ensure that it does not cause us to earn a greater ROE than authorized by the PSCW. In addition, 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.
Wholesale customers who resell power can choose to either bundle capacity and electricity services together under one contract with a supplier or purchase capacity and electricity separately from multiple suppliers. Furthermore, wholesale customers can choose to have us provide generation to match the customer's load, similar to requirements contracts, or they can purchase specified quantities of electricity and capacity. Contracts with wholesale customers that include capacity bundled with the delivery of electricity contain two performance obligations, as capacity and electricity are often transacted separately in the marketplace at the wholesale level. When recognizing revenue associated with these contracts, the transaction price is allocated to each
2024 Form 10-K 61
Wisconsin Public Service Corporation
performance obligation based on its relative standalone selling price. Revenue is recognized as control of each individual component is transferred to the customer. Electricity is the primary product sold by our electric operations and represents a single performance obligation satisfied over time through discrete deliveries to a customer. Revenue from electricity sales is generally recognized as units are produced and delivered to the customer within the production month. Capacity represents the reservation of an electric generating facility and conveys the ability to call on a plant to produce electricity when needed by the customer. The nature of our performance obligation as it relates to capacity is to stand ready to deliver power. This represents a single performance obligation transferred over time, which generally represents a monthly obligation. Accordingly, capacity revenue is recognized on a monthly basis.
The transaction price of the performance obligations for wholesale customers is valued using the rates, charges, terms, and conditions of service, which have been approved by the FERC. These wholesale rates include recovery of fuel and purchased power costs from customers on a one-for-one basis. For the majority of our wholesale customers, the price billed for energy and capacity is a formula-based rate. Formula-based rates initially set a customer's current year rates based on the previous year’s expenses. This is a predetermined formula derived from the utility’s costs and a reasonable rate of return. Because these rates are eventually trued up to reflect actual current-year costs, they represent a form of variable consideration in certain circumstances. The variable consideration is estimated and recognized over time as wholesale customers receive and consume the capacity and electricity services.
We are an active participant in the MISO Energy Markets, where we bid our generation into the Day Ahead and Real Time markets and procure electricity for our retail and wholesale customers at prices determined by the MISO Energy Markets. Purchase and sale transactions are recorded using settlement information provided by MISO. These purchase and sale transactions are accounted for on a net hourly position. Net purchases in a single hour are recorded as purchased power in cost of sales, and net sales in a single hour are recorded as resale revenues on our income statements. For resale revenues, our performance obligation is created only when electricity is sold into the MISO Energy Markets.
For all of our customers, consistent with the timing of when we recognize revenue, customer billings generally occur on a monthly basis, with payments typically due in full within 30 days.
Natural Gas Utility Operating Revenues
We recognize natural gas utility operating revenues under requirements contracts with residential, commercial and industrial, and transportation customers served under our tariffs. Tariffs provide our customers with the standard terms and conditions, including rates, related to the services offered. Requirements contracts provide for the delivery of as much natural gas as the customer needs. These requirements contracts represent discrete deliveries of natural gas and constitute a single performance obligation satisfied over time. Our performance obligation is both created and satisfied with the transfer of control of natural gas upon delivery to the customer. For most of our customers, natural gas is delivered and consumed by the customer simultaneously. A performance obligation can be bundled to consist of both the sale and the delivery of the natural gas commodity. In Wisconsin, our customers can purchase the commodity from a third party. In this case, the performance obligation only includes the delivery of the natural gas to the customer.
The transaction price of the performance obligations for our natural gas customers is valued using the rates, charges, terms, and conditions of service included in our tariffs, which have been approved by the PSCW. These rates often have a fixed component customer charge and a usage-based variable component charge. We recognize revenue for the fixed component customer charge monthly using a time-based output method. We recognize revenue for the usage-based variable component charge using an output method based on natural gas delivered each month.
Our tariffs include various rate mechanisms that allow us to recover or refund changes in prudently incurred costs from rate case-approved amounts. Our rates include a one-for-one recovery mechanism for natural gas commodity costs. Under normal circumstances, we defer any difference between actual natural gas costs incurred and costs recovered through rates as a current asset or liability. The deferred balance is returned to or recovered from customers at intervals throughout the year.
In addition, 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.
Consistent with the timing of when we recognize revenue, customer billings generally occur on a monthly basis, with payments typically due in full within 30 days.
2024 Form 10-K 62
Wisconsin Public Service Corporation
Other Operating Revenues
Alternative Revenues
Alternative revenues are created from programs authorized by regulators that allow us to record additional revenues by adjusting rates in the future, usually as a surcharge applied to future billings, in response to past activities or completed events. We record alternative revenues when the regulator-specified conditions for recognition have been met. We reverse these alternative revenues as the customer is billed, at which time this revenue is presented as revenues from contracts with customers.
Our only alternative revenue program relates to the wholesale electric service that we provide to customers under market-based rates and FERC formula rates. The customer is charged a base rate each year based upon a formula using prior year actual costs and customer demand. A true-up is calculated based on the difference between the amount billed to customers for the demand component of their rates and what the actual cost of service was for the year. The true-up can result in an amount that we will recover from or refund to the customer. We consider the true-up portion of the wholesale electric revenues to be alternative revenues.
(e) Credit Losses-The following discussion includes our significant accounting policies related to credit losses. For additional required disclosures on credit losses, see Note 5, 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 December 31, 2024 and 2023.
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.
(f) Materials, Supplies, and Inventories-Our inventories as of December 31 consisted of:
(in millions) 2024 2023
Materials and supplies $ 100.8 $ 79.9
Fossil fuel 39.9 52.1
Natural gas in storage 26.4 39.1
Total $ 167.1 $ 171.1
Substantially all materials and supplies, fossil fuel, and natural gas in storage inventories are recorded using the weighted-average cost method of accounting.
(g) Regulatory Assets and Liabilities-The economic effects of regulation can result in regulated companies recording costs and revenues that are allowed in the ratemaking process in a period different from the period they would have been recognized by a nonregulated company. When this occurs, regulatory assets and regulatory liabilities are recorded on the balance sheet. Regulatory assets represent deferred costs probable of recovery from customers that would have otherwise been charged to expense.
2024 Form 10-K 63
Wisconsin Public Service Corporation
Regulatory liabilities represent amounts that are expected to be refunded to customers in future rates or future costs already collected from customers in rates.
The recovery or refund of regulatory assets and liabilities is based on specific periods determined by our regulators or occurs over the normal operating period of the related assets and liabilities. If a previously recorded regulatory asset is no longer probable of recovery, the regulatory asset is reduced to the amount considered probable of recovery, and the reduction is charged to expense in the current period. See Note 6, Regulatory Assets and Liabilities, for more information.
(h) Property, Plant, and Equipment-We record property, plant, and equipment at cost. Cost includes material, labor, overhead, and both debt and equity components of AFUDC. Additions to and significant replacements of property are charged to property, plant, and equipment at cost; minor items are charged to other operation and maintenance expense. The cost of depreciable utility property less salvage value is charged to accumulated depreciation when property is retired.
We record straight-line depreciation expense over the estimated useful life of utility property using depreciation rates approved by the PSCW that include estimates for salvage value and removal costs. Annual utility composite depreciation rates were 2.92%, 2.93%, and 2.67% in 2024, 2023, and 2022, respectively.
We capitalize certain costs related to software developed or obtained for internal use and record these costs to amortization expense over the estimated useful life of the related software, which ranges from 3 to 15 years. If software is retired prior to being fully amortized, the difference is recorded as a loss on the income statement.
Third parties reimburse us for all or a portion of expenditures for certain capital projects. Such contributions in aid of construction costs are recorded as a reduction to property, plant, and equipment.
See Note 7, Property, Plant, and Equipment, for more information.
(i) Allowance for Funds Used During Construction-AFUDC is included in utility plant accounts and represents the cost of borrowed funds (AFUDC-Debt) used during plant construction, and a return on shareholders' capital (AFUDC-Equity) used for construction purposes. AFUDC-Debt is recorded as a reduction of interest expense, and AFUDC-Equity is recorded in other income, net.
Approximately 50% of our retail jurisdictional CWIP expenditures are subject to the AFUDC calculation. Our average AFUDC retail rates were 7.46%, 7.46%, and 7.55% for 2024, 2023, and 2022, respectively. Our average AFUDC wholesale rates were 5.53%, 4.60%, and 5.49% for 2024, 2023, and 2022, respectively.
We recorded the following AFUDC for the years ended December 31:
(in millions) 2024 2023 2022
AFUDC-Debt $ 3.6 $ 2.9 $ 2.3
AFUDC-Equity 9.2 7.6 5.8
(j) Asset Impairment-Goodwill and other intangible assets with indefinite lives are subject to an annual impairment test. Interim impairment tests are performed when impairment indicators are present. During the third quarter of each year, we perform an annual goodwill impairment test. The carrying amount of our goodwill is considered not recoverable if the carrying amount of our net assets exceeds our fair value. An impairment loss is recorded as the excess of the carrying amount of the goodwill over its fair value. For our indefinite-lived intangible assets, an impairment loss is recognized when the carrying amount of an asset is not recoverable and exceeds its fair value. An impairment loss is measured as the excess of the carrying amount of the intangible asset over its fair value. No impairment losses were recorded for our indefinite-lived intangible assets during the years ended December 31, 2024, 2023, and 2022. See Note 10, Goodwill and Intangible Assets, for more information.
We periodically assess the recoverability of certain long-lived assets when factors indicate the carrying value of such assets may be impaired or such assets are planned to be sold. Long-lived assets that would be subject to an impairment assessment generally include any assets within regulated operations that may not be fully recovered from our customers as a result of regulatory decisions that will be made in the future. An impairment loss is recognized when the carrying amount of an asset is not recoverable and exceeds its fair value. The carrying amount of an asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. An impairment loss is measured as the excess of the carrying amount of the asset over its fair value.
2024 Form 10-K 64
Wisconsin Public Service Corporation
We assess the likelihood of a disallowance of part of the cost of recently completed plant by considering factors such as applicable regulatory environment changes, our own recent rate orders, as well as recent rate orders of other regulated entities in similar jurisdictions. When it becomes probable that part of the cost of recently completed plant will be disallowed for rate-making purposes, we assess whether a reasonable estimate of the amount of the disallowance can be made. The estimated amount of the probable disallowance will then be deducted from the reported cost of the plant and recognized as an impairment loss.
When it becomes probable that a generating unit will be retired before the end of its useful life, we assess whether the generating unit meets the criteria for abandonment accounting. Generating units that are considered probable of abandonment are expected to cease operations in the near term, significantly before the end of their original estimated useful lives. If a generating unit meets the applicable criteria to be considered probable of abandonment, and the unit has been abandoned, we assess the likelihood of recovery of the remaining net book value of that generating unit at the end of each reporting period. If it becomes probable that regulators will disallow full recovery as well as a return on the remaining net book value of a generating unit that is either abandoned or probable of being abandoned, an impairment loss may be required. An impairment loss would be recorded if the remaining net book value of the generating unit is greater than the present value of the amount expected to be recovered from ratepayers, using an incremental borrowing rate. See Note 6, Regulatory Assets and Liabilities, and Note 7, Property, Plant, and Equipment, for more information.
We periodically assess the recoverability of equity method investments when factors indicate the carrying amount of such assets may be impaired. Equity method investments are assessed for impairment by comparing the fair values of these investments to their carrying amounts if a fair value assessment was completed or by reviewing for the presence of impairment indicators. If an impairment exists, and it is determined to be other-than-temporary, an impairment loss is recognized equal to the amount by which the carrying amount exceeds the investment's fair value.
(k) Asset Retirement Obligations-We recognize, at fair value, legal obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development, and normal operation of the assets. An ARO liability is recorded, when incurred, for these obligations as long as the fair value can be reasonably estimated, even if the timing or method of settling the obligation is unknown. The associated retirement costs are capitalized as part of the related long-lived asset and are depreciated over the useful life of the asset. The ARO liabilities are accreted each period using the credit-adjusted risk-free interest rates associated with the expected settlement dates of the AROs. These rates are determined when the obligations are incurred. Subsequent changes resulting from revisions to the timing or the amount of the original estimate of undiscounted cash flows are recognized as an increase or a decrease to the carrying amount of the liability and the associated capitalized retirement costs. We recognize regulatory assets or liabilities for the timing differences between when we recover an ARO in rates and when we recognize the associated retirement costs. See Note 9, Asset Retirement Obligations, for more information.
(l) Stock-Based Compensation-Our employees participate in the WEC Energy Group stock-based compensation plans. In accordance with the Omnibus Stock Incentive Plan, WEC Energy Group provides long-term incentives through its equity interests to its non-employee directors, officers, and other key employees. The plan provides for the granting of stock options, restricted stock, performance shares, and other stock-based awards. Awards may be paid in WEC Energy Group common stock, cash, or a combination thereof. In addition to those shares of WEC Energy Group common stock that were subject to awards outstanding as of May 6, 2021, when the plan was last approved by shareholders, 9.0 million shares of WEC Energy Group common stock were reserved for issuance under the plan.
Stock-based compensation expense is allocated to us based on the outstanding awards held by our employees and our allocation of labor costs. Awards classified as equity awards are measured based on their grant-date fair value. Awards classified as liability awards are recorded at fair value each reporting period. We account for forfeitures as they occur, rather than estimating potential future forfeitures and recording them over the vesting period.
Stock Options
Our employees are granted WEC Energy Group non-qualified stock options that generally vest on a cliff-basis after three years. The exercise price of a stock option under the plan cannot be less than 100% of the fair market value of WEC Energy Group common stock on the grant date. Historically, all stock options have been granted with an exercise price equal to the fair market value of WEC Energy Group common stock on the date of the grant. Options vest immediately upon retirement, death, or disability; however, they may not be exercised within six months of the grant date except in connection with certain termination of employment events following a change in control. Options expire no later than 10 years from the date of grant.
2024 Form 10-K 65
Wisconsin Public Service Corporation
WEC Energy Group stock options are classified as equity awards. The fair value of each stock option was calculated using a binomial option-pricing model. The following table shows the estimated weighted-average fair value per stock option granted to our employees along with the weighted-average assumptions used in the valuation models:
2024 2023 2022
Stock options granted 11,878 10,655 16,079
Estimated weighted-average fair value per stock option $ 16.20 $ 19.58 $ 14.71
Assumptions used to value the options:
Risk-free interest rate 3.9% - 5.2%
3.8% - 4.8%
0.2% - 1.6%
Dividend yield 3.8 % 3.2 % 3.2 %
Expected volatility 22.0 % 22.0 % 21.0 %
Expected life (years) 8.4 8.3 8.7
The risk-free interest rate was based on the United States Treasury interest rate with a term consistent with the expected life of the stock options. The dividend yield was based on WEC Energy Group's dividend rate at the time of the grant and historical stock prices. Expected volatility and expected life assumptions were based on WEC Energy Group's historical experience.
Restricted Shares
WEC Energy Group restricted shares granted to our employees have a vesting period of three years with one-third of the award vesting on each anniversary of the grant date. The restricted shares are classified as equity awards.
Performance Units
Officers and other key employees are granted performance units under the WEC Energy Group Performance Unit Plan. All grants of performance units are settled in cash and are accounted for as liability awards accordingly. Performance units accrue forfeitable dividend equivalents in the form of additional performance units. The fair value of the performance units reflects our estimate of the final expected value of the awards, which is based on WEC Energy Group's stock price and performance achievement under the terms of the award. Stock-based compensation costs are generally recorded over the performance period, which is three years.
The ultimate number of performance units that will be paid out is dependent on WEC Energy Group's total shareholder return (stock price appreciation plus dividends) as compared to the total shareholder return of a peer group of companies over three years, as well as other performance metrics, as may be determined by the Compensation Committee. Under the terms of awards granted prior to 2023, participants may earn between 0% and 175% of the performance unit award based on WEC Energy Group's total shareholder return. Pursuant to the plan terms governing these awards, these percentages can be adjusted upwards or downwards by up to 10% based on WEC Energy Group's performance against additional performance measures, if any, adopted by the Compensation Committee.
The WEC Energy Group Performance Unit Plan was amended and restated, effective January 1, 2023. In accordance with the amended plan, the Compensation Committee selected multiple performance measures that will be weighted to determine the ultimate payout for the awards granted in 2023, 2024, and 2025. The ultimate number of units that will be paid out will be based on WEC Energy Group's total shareholder return compared to the total shareholder return of a peer group of companies over three years (55%), and WEC Energy Group's performance against the weighted average authorized ROE of all of its utility subsidiaries (45%). In addition, the Compensation Committee selected the level of WEC Energy Group's stock price to earnings ratio compared to its peer companies as a performance measure that can increase the payout by up to 25%. In no event can the performance unit payout be greater than 200% of the target award.
See Note 11, Common Equity, for more information on WEC Energy Group's stock-based compensation plans.
(m) Leases-We recognize a right of use asset and lease liability for operating and finance leases with a term of greater than one year. As a policy election, we account for each lease component separately from the nonlease components of a contract.
2024 Form 10-K 66
Wisconsin Public Service Corporation
We are currently party to several easement agreements that allow us access to land we do not own for the purpose of constructing and maintaining certain electric power and natural gas equipment. The majority of payments we make related to easements relate to our renewable generating facilities. We have not classified our easements as leases because we view the entire parcel of land specified in our easement agreements to be the identified asset, not just that portion of the parcel that contains our easement. As such, we have concluded that we do not control the use of an identified asset related to our easement agreements, nor do we obtain substantially all of the economic benefits associated with these shared-use assets.
See Note 15, Leases, for more information.
(n) Income Taxes-We follow the liability method in accounting for income taxes. Accounting guidance for income taxes requires the recording of deferred assets and liabilities to recognize the expected future tax consequences of events that have been reflected in our financial statements or tax returns and the adjustment of deferred tax balances to reflect tax rate changes. We are required to assess the likelihood that our deferred tax assets would expire before being realized. If we conclude that certain deferred tax assets are likely to expire before being realized, a valuation allowance would be established against those assets. GAAP requires that, if we conclude in a future period that it is more likely than not that some or all of the deferred tax assets would be realized before expiration, we reverse the related valuation allowance in that period. Any change to the allowance, as a result of a change in judgment about the realization of deferred tax assets, is reported in income tax expense.
ITCs associated with regulated operations are deferred and amortized over the life of the assets. PTCs are recognized in the period in which such credits are generated. The amount of the credit is based upon power production from our qualifying generation facilities. We are included in WEC Energy Group's consolidated federal and state income tax returns. In accordance with our tax allocation agreement with WEC Energy Group, we are allocated income tax payments and refunds based upon the benefit for loss method, where attributes are realized when WEC Energy Group is able to realize them.
We recognize interest and penalties accrued related to unrecognized tax benefits in income tax expense in our income statements.
The IRA contains a tax credit transferability provision that allows us to sell PTCs produced after December 31, 2022, to third parties. In 2023 and 2024, under this transferability provision, WEC Energy Group entered into an agreement to sell substantially all of the PTCs we generated in 2023 and 2024 to third parties. In October 2024, WEC Energy Group entered into an agreement to sell the majority of the PTCs expected to be generated in 2025 to a third party. We elect to account for tax credits transferred under the scope of ASC 740. We include the discount from the sale of tax credits as a component of income tax expense. We 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 is presented in the operating activities section of the statements of cash flows consistent with the presentation of cash taxes paid.
In April 2023, the IRS issued Revenue Procedure 2023-15, which provides a safe harbor method of accounting that taxpayers may use to determine whether expenses to repair, maintain, replace, or improve natural gas transmission and distribution property must be capitalized for tax purposes. We adopted the safe harbor method of accounting on our 2023 tax return, which increased our deferred tax liabilities.
See Note 16, Income Taxes, for more information.
(o) Fair Value Measurements-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.
2024 Form 10-K 67
Wisconsin Public Service Corporation
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.
See Note 17, Fair Value Measurements, for more information.
(p) 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 assets or liabilities 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.
We classify derivative assets and liabilities as current or long-term on our balance sheets based on the maturities of the underlying contracts. Cash flows from derivative activities are presented in the same category as the item being hedged within operating activities on our statements of cash flows.
Derivative accounting rules provide the option to present certain asset and liability derivative positions net on the balance sheets and to net the related cash collateral against these net derivative positions. We elected not to net these items. On our balance sheets, cash collateral provided to others is reflected in other current assets, and cash collateral received is reflected in other current liabilities. See Note 18, Derivative Instruments, for more information.
(q) Guarantees-We follow the guidance of the Guarantees Topic of the FASB ASC, which requires, under certain circumstances, that the guarantor recognize a liability for the fair value of the obligation undertaken in issuing the guarantee at its inception. As of December 31, 2024, 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.
(r) Employee Benefits-The costs of pension and OPEB plans are expensed over the periods during which employees render service. These costs are distributed among WEC Energy Group's subsidiaries based on current employment status and actuarial calculations, as applicable. Our regulators allow recovery in rates for our net periodic benefit cost calculated under GAAP. See Note 19, Employee Benefits, for more information.
(s) Customer Deposits and Credit Balances-When utility customers apply for new service, they may be required to provide a deposit for the service. Customer deposits are recorded within other current liabilities on our balance sheets.
Utility customers can elect to be on a budget plan. Under this type of plan, a monthly installment amount is calculated based on estimated annual usage. During the year, the monthly installment amount is reviewed by comparing it to actual usage. If necessary, an adjustment is made to the monthly amount. Annually, the budget plan is reconciled to actual annual usage. Payments in excess of actual customer usage are recorded within other current liabilities on our balance sheets.
2024 Form 10-K 68
Wisconsin Public Service Corporation
(t) Environmental Remediation Costs-We are subject to federal and state environmental laws and regulations that in the future may require us to pay for environmental remediation at sites where we have been, or may be, identified as a potentially responsible party. Loss contingencies may exist for the remediation of hazardous substances at various potential sites, including CCR landfills and manufactured gas plant sites. See Note 9, Asset Retirement Obligations, for more information regarding CCR landfills and Note 21, Commitments and Contingencies, for more information regarding manufactured gas plant sites.
We record environmental remediation liabilities when site assessments indicate remediation is probable, and we can reasonably estimate the loss or a range of losses. The estimate includes both our share of the liability and any additional amounts that will not be paid by other potentially responsible parties or the government. When possible, we estimate costs using site-specific information but also consider historical experience for costs incurred at similar sites. Remediation efforts for a particular site generally extend over a period of several years. During this period, the laws governing the remediation process may change, as well as site conditions, potentially affecting the cost of remediation.
We have received approval to defer certain environmental remediation costs, as well as estimated future costs, through a regulatory asset. The recovery of deferred costs is subject to the PSCW's approval.
We review our estimated costs of remediation annually for our manufactured gas plant sites and CCR landfills. We adjust the liabilities and related regulatory assets, as appropriate, to reflect the new cost estimates. Any material changes in cost estimates are adjusted throughout the year.
(u) Customer Concentrations of Credit Risk-The geographic concentration of our customers did not contribute significantly to our overall exposure to credit risk. We periodically review customers' credit ratings, financial statements, and historical payment performance and require them to provide collateral or other security as needed. Our credit risk exposure is mitigated by our recovery mechanism for uncollectible expense discussed in Note 1(d), Operating Revenues. As a result, we did not have any significant concentrations of credit risk at December 31, 2024. In addition, there were no customers that accounted for more than 10% of our revenues for the year ended December 31, 2024.
NOTE 2-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 $145.9 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.
NOTE 3-RELATED PARTIES
We routinely enter into transactions with related parties, including WEC Energy Group, its other subsidiaries, ATC, and other affiliated entities.
We provide and receive services, property, and other items of value to and from our ultimate parent, WEC Energy Group, and other subsidiaries of WEC Energy Group pursuant to an AIA that became effective in 2017. The AIA was approved by the appropriate regulators, including the PSCW. In accordance with the AIA, WBS provides several categories of services to us (including financial, human resource, and administrative services). As required by FERC regulations for centralized service companies, WBS renders services at cost. Services provided by any regulated subsidiary of WEC Energy Group to another regulated subsidiary or WBS are provided at cost, and any services provided by a regulated subsidiary to a nonregulated subsidiary of WEC Energy Group are provided at the greater of cost or fair market value.
2024 Form 10-K 69
Wisconsin Public Service Corporation
We provide services to WRPC under an operating agreement approved by the PSCW. We are also under a service agreement with WRPC where we are billed for services provided by WRPC. Services are billed to and from WRPC under these agreements at a fully allocated cost.
We pay ATC for transmission and other related services it provides. In addition, we provide a variety of operational, maintenance, and project management work for ATC, which is reimbursed by ATC. Services are billed to and from ATC under agreements approved by the PSCW, at each of our fully allocated costs. We are also required to initially fund the construction of transmission infrastructure upgrades needed for new generation projects. ATC owns these transmission assets and reimburses us for these costs when the new generation is placed in service.
Our balance sheets included the following receivables and payables for services provided to or received from ATC:
(in millions) December 31, 2024 December 31, 2023
Accounts receivable
Services provided to ATC $ 0.5 $ 0.7
Amounts due from ATC for transmission infrastructure upgrades (1)
7.9 6.6
Accounts payable
Services received from ATC 10.5 12.0
(1) The transmission infrastructure upgrades were primarily related to the construction of our renewable energy projects.
The following table shows activity associated with our related party transactions for the years ended December 31:
(in millions) 2024 2023 2022
Transactions with WE
Natural gas related sales to WE (1)
$ 1.0 $ 1.3 $ 3.3
Charges to WE for services and other items (2)
12.8 11.3 10.7
Charges from WE for services and other items (2)
18.6 16.2 13.3
Transactions with WG
Natural gas related sales to WG (1)
- 1.4 0.4
Charges to WG for services and other items (2)
2.1 1.0 1.1
Charges from WG for services and other items (2)
0.8 0.7 1.0
Transactions with UMERC
Natural gas related sales to UMERC (1)
2.1 3.1 4.0
Charges to UMERC for services and other items (2)
5.1 2.2 3.7
Transactions with Bluewater
Charges from Bluewater for storage service fees (3)
14.1 12.1 10.7
Charges from Bluewater for other operating fees (3)
2.7 2.7 2.3
Natural gas related sales to Bluewater (1)
1.9 1.9 1.9
Transactions with WBS
Charges to WBS for services and other items (2)
7.7 13.1 16.1
Charges from WBS for services and other items (2)
60.5 55.6 62.4
Transactions with ATC
Charges to ATC for services and construction 9.2 9.3 9.6
Charges from ATC for network transmission services 126.0 114.2 109.5
Transactions with WRPC
Rental payments to WRPC (4)
2.5 2.5 1.9
Charges to WRPC for services 0.3 0.4 0.4
Charges from WRPC for services 3.0 2.8 2.6
(1) Includes amounts related to the sale of natural gas and/or pipeline capacity.
(2) Includes amounts charged for services, pass through costs, asset and liability transfers, and other items in accordance with the approved AIA.
(3) We have a long-term service agreement with a wholly owned subsidiary of Bluewater that was previously approved by the PSCW. Bluewater owns natural gas storage facilities in Michigan and provides a portion of our current storage needs.
(4) We have an agreement with WRPC whereby we receive 50% of the energy generated from its hydroelectric power generation facilities.
2024 Form 10-K 70
Wisconsin Public Service Corporation
NOTE 4-OPERATING REVENUES
For more information about our significant accounting policies related to operating revenues, see Note 1(d), Operating Revenues.
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.
Year Ended December 31
(in millions) 2024 2023 2022
Wisconsin Public Service Corporation
Electric utility $ 1,245.2 $ 1,309.9 $ 1,316.5
Natural gas utility 315.2 368.0 465.5
Total revenues from contracts with customers 1,560.4 1,677.9 1,782.0
Other operating revenues - 3.5 3.2
Total operating revenues $ 1,560.4 $ 1,681.4 $ 1,785.2
Revenues from Contracts with Customers
Electric Utility Operating Revenues
The following table disaggregates electric utility operating revenues into customer class:
Year Ended December 31
(in millions) 2024 2023 2022
Residential $ 460.1 $ 479.9 $ 460.4
Small commercial and industrial 421.7 445.9 413.8
Large commercial and industrial 256.2 273.1 293.3
Other 8.5 8.7 8.8
Total retail revenues 1,146.5 1,207.6 1,176.3
Wholesale 57.1 79.2 95.4
Resale 29.8 17.8 27.3
Other utility revenues 11.8 5.3 17.5
Total electric utility operating revenues $ 1,245.2 $ 1,309.9 $ 1,316.5
Natural Gas Utility Operating Revenues
The following table disaggregates natural gas utility operating revenues into customer class:
Year Ended December 31
(in millions) 2024 2023 2022
Residential $ 185.5 $ 219.8 $ 271.8
Commercial and industrial 99.1 124.2 175.1
Total retail revenues 284.6 344.0 446.9
Transportation 22.5 22.3 20.1
Other utility revenues (1)
8.1 1.7 (1.5)
Total natural gas utility operating revenues $ 315.2 $ 368.0 $ 465.5
(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.
2024 Form 10-K 71
Wisconsin Public Service Corporation
Other Operating Revenues
Other operating revenues consist of the following:
Year Ended December 31
(in millions) 2024 2023 2022
Late payment charges $ 3.3 $ 3.9 $ 3.8
Rental revenues 0.4 0.3 0.3
Alternative revenues (1)
(3.7) (0.7) (0.9)
Total other operating revenues $ - $ 3.5 $ 3.2
(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. For more information about our alternative revenues, see Note 1(d), Operating Revenues.
NOTE 5-CREDIT LOSSES
The table below shows our gross third-party receivable balances and related allowance for credit losses.
(in millions) December 31, 2024 December 31, 2023
Accounts receivable and unbilled revenues $ 233.7 $ 230.1
Allowance for credit losses 8.6 10.9
Accounts receivable and unbilled revenues, net (1)
$ 225.1 $ 219.2
Total accounts receivable, net - past due greater than 90 days (1)
$ 7.4 $ 8.3
Past due greater than 90 days - collection risk mitigated by regulatory mechanisms (1)
93.9 % 93.4 %
(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 December 31, 2024, $126.3 million, or 56.1%, 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:
Year Ended December 31
(in millions) 2024 2023 2022
Balance at January 1 $ 10.9 $ 11.7 $ 11.1
Provision for credit losses 7.8 5.6 8.4
Provision for credit losses deferred for future recovery or refund 0.8 3.3 0.1
Write-offs charged against the allowance (15.5) (14.9) (12.8)
Recoveries of amounts previously written off 4.6 5.2 4.9
Balance at December 31 $ 8.6 $ 10.9 $ 11.7
The allowance for credit losses decreased during the year ended December 31, 2024, largely driven by increased customer write-offs. After a customer is disconnected for a period of time without payment on their account, we will write off that customer balance. We also believe that the lower energy costs that customers were seeing, which were driven by warmer than normal weather conditions during most of 2024 and low average natural gas prices, contributed to a reduction in past due accounts receivable balances and a related decrease in the allowance for credit losses.
The allowance for credit losses decreased during the year ended December 31, 2023, primarily related to lower customer energy costs (driven by the warmer weather during the fourth quarter of 2023 when compared to the same quarter in 2022 and lower natural gas prices), which contributed to a reduction in past due accounts receivable balances and a related decrease in the allowance for credit losses. Customer write-offs also contributed to the decrease in the allowance for credit losses.
The allowance for credit losses increased during the year ended December 31, 2022. We believe that the high energy costs that customers were seeing, 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. The increase was substantially offset by customer write-offs related to collection practices returning to pre-pandemic levels, including the restoration of our ability to disconnect customers.
2024 Form 10-K 72
Wisconsin Public Service Corporation
NOTE 6-REGULATORY ASSETS AND LIABILITIES
The following regulatory assets were reflected on our balance sheets as of December 31:
(in millions) 2024 2023 See Note
Regulatory assets (1) (2)
Plant retirement related items (3)
$ 143.6 $ 38.4 21
Environmental remediation costs (4)
114.0 121.5 21
Income tax related items 55.1 57.2 16
Pension and OPEB costs (5)
45.6 62.0 19, 23
AROs 27.5 18.8 1(k), 9
Bluewater (6)
13.4 11.9
Reactive power (7)
13.4 6.8
ReACT™ (8)
7.8 10.4
Derivatives 1.9 12.5 1(p)
Other, net 27.4 21.1
Total regulatory assets $ 449.7 $ 360.6
(1) Based on prior and current rate treatment, we believe it is probable that we will continue to recover from customers the regulatory assets in this table. In accordance with GAAP, our regulatory assets do not include the allowance for ROE that is capitalized for regulatory purposes. This allowance was $5.8 million and $7.7 million at December 31, 2024 and 2023, respectively.
(2) As of December 31, 2024, we had $37.1 million of regulatory assets not earning a return. The regulatory assets not earning a return primarily relate to certain environmental remediation costs. The other regulatory assets in the table either earn a return at our weighted average cost of capital or the cash has not yet been expended, in which case the regulatory assets are offset by liabilities.
(3) At December 31, 2024, plant retirement related items included $101.3 million of capitalized retirement costs related to the new EPA CCR Rule that was enacted in April 2024.
(4) As of December 31, 2024, we had made cash expenditures of $36.7 million related to these environmental remediation costs. The remaining $77.3 million represents our estimated future cash expenditures.
(5) Primarily represents the unrecognized future pension and OPEB costs related to our defined benefit pension and OPEB plans. We are authorized recovery of these regulatory assets over the average remaining service life of each plan.
(6) Primarily relates 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.
(7) In January 2023, the FERC issued an order that eliminated the reactive power reimbursement from MISO, retroactive to December 1, 2022. Due to this FERC order, in August 2023, the PSCW approved the deferral of the previously reimbursed transmission expenses from December 1, 2022 through December 31, 2024. We are recovering this regulatory asset over a period of two years that began on January 1, 2025. As of January 1, 2025, these transmission expenses are included in our base rates.
(8) In accordance with the rate order we received from the PSCW in December 2019, we are allowed to collect the previously deferred revenue requirement for ReACT™ costs above the authorized $275 million level. The total cost of the ReACT™ project was $342 million. We are recovering this regulatory asset over a period of eight years that began on January 1, 2020.
2024 Form 10-K 73
Wisconsin Public Service Corporation
The following regulatory liabilities were reflected on our balance sheets as of December 31:
(in millions) 2024 2023 See Note
Regulatory liabilities
Income tax related items $ 322.0 $ 331.4 16
Removal costs (1)
206.6 191.2
Pension and OPEB benefits (2)
88.6 85.3 19, 23
Energy costs refundable through rate adjustments 49.2 36.3 1(d)
Other, net 30.2 36.3
Total regulatory liabilities $ 696.6 $ 680.5
Balance sheet presentation
Other current liabilities $ 0.3 $ 8.5
Regulatory liabilities 696.3 672.0
Total regulatory liabilities $ 696.6 $ 680.5
(1) Represents amounts collected from customers to cover the future cost of property, plant, and equipment removals that are not legally required. Legal obligations related to the removal of property, plant, and equipment are recorded as AROs. See Note 9, Asset Retirement Obligations, for more information on our legal obligations.
(2) Primarily represents the unrecognized future pension and OPEB benefits related to our defined benefit pension and OPEB plans. We will amortize these regulatory liabilities into net periodic benefit cost over the average remaining service life of each plan.
J.P. Pulliam Generating Station
In connection with a MISO ruling, we retired Pulliam Units 7 and 8 on October 21, 2018. The net book value of the Pulliam units was $29.3 million at December 31, 2024, representing book value less cost of removal and accumulated depreciation. This amount was classified as a regulatory asset on our balance sheet at December 31, 2024 as a result of the retirement of the plant. Effective with our rate order issued by the PSCW in December 2019, we received approval to collect a return of and on the entire net book value of the Pulliam units, and as a result, will continue to amortize this regulatory asset on a straight-line basis through 2031, using the composite depreciation rates approved by the PSCW before these generating units were retired. The amortization is included in depreciation and amortization in the income statement. We also have FERC approval to continue to collect the net book value of the Pulliam power plant using the approved composite depreciation rates, in addition to a return on the remaining net book value.
Edgewater Generating Station Unit 4
The Edgewater 4 generating unit was retired on September 28, 2018. The net book value of the generating unit was $1.0 million at December 31, 2024, representing book value less cost of removal and accumulated depreciation. This amount was classified as a regulatory asset on our balance sheet at December 31, 2024 as a result of the retirement of the plant. Effective with our rate order issued by the PSCW in December 2019, we received approval to collect a return of and on the entire net book value of the Edgewater 4 generating unit, and as a result, will continue to amortize this regulatory asset on a straight-line basis through 2026, using the composite depreciation rates approved by the PSCW before this generating unit was retired. The amortization is included in depreciation and amortization in the income statement. We also have FERC approval to continue to collect the net book value of the Edgewater 4 generating unit using the approved composite depreciation rates, in addition to a return on the remaining net book value.
2024 Form 10-K 74
Wisconsin Public Service Corporation
NOTE 7-PROPERTY, PLANT, AND EQUIPMENT
Property, plant, and equipment consisted of the following at December 31:
(in millions) 2024 2023
Electric - generation $ 3,226.3 $ 3,108.8
Electric - distribution 2,516.5 2,338.5
Natural gas - distribution, storage, and transmission 1,328.0 1,266.3
Property, plant, and equipment to be retired, net 248.9 259.8
Other 553.7 513.3
Less: Accumulated depreciation 2,004.0 1,857.8
Net 5,869.4 5,628.9
CWIP 269.8 172.5
Total property, plant, and equipment $ 6,139.2 $ 5,801.4
Severance Liability for Plant Retirements
We have severance liabilities related to past and future plant retirements recorded in other current and other long-term liabilities on our balance sheets. Activity related to these severance liabilities for the years ended December 31 was as follows:
(in millions) 2024 2023 2022
Severance liability at January 1 $ 2.7 $ 2.7 $ 1.6
Severance expense (0.5) (1)
- 1.1
Total severance liability at December 31 $ 2.2 $ 2.7 $ 2.7
(1) The severance accrual was decreased in 2024 due to workforce realignment efforts.
Plant to be Retired
Columbia Energy Center 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 the end of 2029, and we are exploring the conversion of at least one unit to natural gas. The total net book value of our ownership share of Columbia Units 1 and 2 was $248.9 million at December 31, 2024, 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.
NOTE 8-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 have supplied our own financing for all jointly owned projects. We pay our ownership share of additional construction costs, fuel inventory purchases, and operating expenses, unless specific agreements have been executed to limit our maximum exposure to additional costs. 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.
2024 Form 10-K 75
Wisconsin Public Service Corporation
Information related to jointly owned utility facilities at December 31, 2024 was as follows:
Jointly-Owned Utility Facilities Ownership Share of Capacity (MW) In-Service /Acquisition Date
Operating Owner Property, Plant, and Equipment Accumulated Depreciation CWIP
(in millions, except for percentages and MW)
Weston Unit 4 (1)
70.0 % 383.4 2008 WPS $ 600.9 $ (230.7) $ 1.6
Columbia Units 1 and 2 (1 ) (4)
27.5 % 307.5 1975 & 1978 WPL 436.5 (186.9) 4.0
Forward Wind (2)
44.6 % 61.5 2008 WPS 120.1 (60.0) -
Two Creeks (3)
66.7 % 100.0 2020 WPS 136.9 (18.6) -
Badger Hollow I (3)
66.7 % 100.0 2021 WPS 146.5 (14.5) 0.4
Red Barn (2)
90.0 % 82.4 2023 WPS 150.6 (8.1) -
Weston RICE units (1)
50.0 % 65.0 2023 WPS 91.8 (4.3) -
Whitewater (1)
50.0 % 117.6 2023 WE 126.2 (95.7) 2.1
Paris (solar portion) (3)
15.0 % 30.0 2024 WE 58.7 - 0.1
(1) Capacity is based on rated capacity, which is the net power output under average operating conditions with equipment in an average state of repair as of a given month in a given year. Values are primarily based on the net dependable expected capacity ratings for summer 2025 established by tests and may change slightly from year to year. The summer period is the most relevant for capacity planning purposes. This is a result of continually reaching demand peaks in the summer months, primarily due to air conditioning demand.
(2) Capacity for wind generating facilities is based on nameplate capacity, which is the amount of energy a turbine should produce at optimal wind speeds.
(3) Capacity for solar generating facilities is based on nameplate capacity, which is the maximum output that a generator should produce at continuous full power.
(4) These coal units are expected to be retired by the end of 2029. See Note 7, Property, Plant, and Equipment, for more information.
We, along with WE and an unaffiliated utility, received PSCW approval to construct Paris, a utility-scale solar-powered electric generating facility with a battery energy storage system. The solar portion of this project went into service in December 2024 (see details in the table above) and construction of the battery storage is expected to be completed in 2025. Once fully constructed, we will own 15%, or 17 MWs of battery storage of this project. Our CWIP balance for Paris was $35.9 million as of December 31, 2024.
We, along with WE and an unaffiliated utility, received PSCW approval to construct Darien, a utility-scale solar-powered electric generating facility with a battery energy storage system. Once fully constructed, we will own 15%, or 37 MWs of solar generation and 12 MWs of battery storage of this project. Commercial operation of the solar portion and the battery storage is expected to be completed in 2025 and 2026, respectively. Our CWIP balance for Darien was $69.8 million as of December 31, 2024.
We, along with WE and an unaffiliated utility, received PSCW approval to construct Koshkonong, a utility-scale solar-powered electric generating facility with a battery energy storage system. Once fully constructed, we will own 15%, or 45 MWs of solar generation and 25 MWs of battery storage of this project. Commercial operation of the solar facility and the battery storage is expected to be completed in 2026 and 2027, respectively. Our CWIP balance for Koshkonong was $23.4 million as of December 31, 2024.
NOTE 9-ASSET RETIREMENT OBLIGATIONS
We have recorded AROs primarily for asbestos abatement at certain generation facilities, office buildings, and service centers; the dismantling of solar and wind generation projects; the disposal of polychlorinated biphenyls-contaminated transformers; and the closure of CCR landfills at certain generation facilities. We establish regulatory assets and liabilities to record the differences between ongoing expense recognition under the ARO accounting rules and the ratemaking practices for retirement costs authorized by the PSCW.
2024 Form 10-K 76
Wisconsin Public Service Corporation
The following table shows changes to our AROs during the years ended December 31:
(in millions) 2024 2023 2022
Balance as of January 1 $ 56.7 $ 55.1 $ 55.8
Accretion 5.3 2.1 2.0
Additions 140.1 (1)
2.2 0.7
Revisions to estimated cash flows (5.6) 1.6 1.4
Liabilities settled (5.3) (4.3) (4.8)
Balance as of December 31 $ 191.2 $ 56.7 $ 55.1
(1) AROs increased primarily as a result of AROs being recorded related to the new EPA CCR Rule that was enacted in April 2024. See Note 21, Commitments and Contingencies, for more information.
NOTE 10-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 years ended December 31, 2024 and 2023. We had no accumulated impairment losses related to our goodwill as of December 31, 2024.
During the third quarter of 2024, we completed our annual goodwill impairment test for goodwill we carried as of July 1, 2024. No impairment resulted from this test.
Other Indefinite-Lived Intangible Assets
At December 31, 2024 and 2023, we had $5.3 million of other indefinite-lived intangible assets, consisting of spectrum frequencies. The spectrum frequencies enable us to transmit data and voice communications over a wavelength dedicated to us throughout our service territory. These indefinite-lived intangible assets are included in other long-term assets on our balance sheets.
NOTE 11-COMMON EQUITY
Stock-Based Compensation
The following table summarizes our pre-tax stock-based compensation expense, including amounts allocated from WBS, and the related tax benefit recognized in income for the years ended December 31:
(in millions) 2024 2023 2022
Stock options $ 0.8 $ 1.0 $ 1.1
Restricted stock 1.3 1.1 1.2
Performance units 4.8 (0.4) (1)
3.9
Stock-based compensation expense $ 6.9 $ 1.7 $ 6.2
Related tax benefit $ 1.9 $ 0.5 $ 1.7
(1) The reduction in expense was due to a decrease in the fair value of the outstanding performance units.
Stock-based compensation costs capitalized during 2024, 2023, and 2022 were not significant.
2024 Form 10-K 77
Wisconsin Public Service Corporation
Stock Options
The following is a summary of our employees' WEC Energy Group stock option activity during 2024:
Stock Options Number of Options Weighted-Average Exercise Price Weighted-Average Remaining Contractual Life
(in years)
Aggregate Intrinsic Value
(in millions)
Outstanding as of January 1, 2024 75,277 $ 87.58
Granted 11,878 85.05
Exercised (13,871) 80.31
Outstanding as of December 31, 2024 73,284 88.54 6.4 $ 0.4
Exercisable as of December 31, 2024 38,977 85.62 5.1 $ 0.3
The aggregate intrinsic value of outstanding and exercisable options in the above table represents the total pre-tax intrinsic value that would have been received by the option holders had they exercised all of their options on December 31, 2024. This is calculated as the difference between WEC Energy Group's closing stock price on December 31, 2024, and the option exercise price, multiplied by the number of in-the-money stock options. The intrinsic value of options exercised during the years ended December 31, 2024 and 2022 was $0.3 million and $0.9 million, respectively. No stock options were exercised by our employees during the year ended December 31, 2023. Cash received by WEC Energy Group from exercises of its options by our employees was $1.1 million and $2.4 million during the years ended December 31, 2024 and 2022, respectively. The actual tax benefit from option exercises for the same years was approximately $0.1 million and $0.2 million, respectively.
As of December 31, 2024, we expected to recognize approximately $0.2 million of unrecognized compensation cost related to unvested and outstanding WEC Energy Group stock options over the next 1.7 years on a weighted-average basis.
During the first quarter of 2025, the Compensation Committee awarded 10,117 non-qualified WEC Energy Group stock options with an exercise price of $94.55 and a weighted-average grant date fair value of $18.23 per option to certain of our officers and other key employees under its normal schedule of awarding long-term incentive compensation.
Restricted Shares
The following is a summary of our employees' WEC Energy Group restricted stock activity during 2024:
Restricted Shares Number of Shares Weighted-Average Grant Date Fair Value
Outstanding and unvested as of January 1, 2024 2,985 $ 94.07
Granted 2,783 85.05
Released (1,416) 93.69
Forfeited (375) 88.72
Outstanding and unvested as of December 31, 2024 3,977 88.39
The intrinsic value of WEC Energy Group restricted stock held by our employees that was released was $0.1 million for each of the years ended December 31, 2024, 2023, and 2022. The actual tax benefit from released restricted shares for the same years was not significant.
As of December 31, 2024, we expected to recognize approximately $0.7 million of unrecognized compensation cost related to unvested and outstanding WEC Energy Group restricted stock over the next 1.8 years on a weighted-average basis.
During the first quarter of 2025, the Compensation Committee awarded 2,501 WEC Energy Group restricted shares to our officers and other key employees under its normal schedule of awarding long-term incentive compensation. The grant date fair value of these awards was $94.55 per share.
Performance Units
During 2024, 2023, and 2022, the Compensation Committee awarded 9,061; 6,905; and 6,608 WEC Energy Group performance units, respectively, to our officers and other key employees under the WEC Energy Group Performance Unit Plan.
2024 Form 10-K 78
Wisconsin Public Service Corporation
Performance units with an intrinsic value of $0.1 million, $0.4 million, and $0.7 million were settled during 2024, 2023, and 2022, respectively. The actual tax benefit from the distribution of performance units for the year ended December 31, 2024 was not significant. The actual tax benefit from the distribution of performance units for the years ended December 31, 2023 and 2022 was $0.1 million and $0.2 million, respectively.
At December 31, 2024, our employees held 21,706 WEC Energy Group performance units, including dividend equivalents. A liability of $1.6 million was recorded on our balance sheet at December 31, 2024 related to these outstanding units. As of December 31, 2024, we expected to recognize approximately $3.9 million of unrecognized compensation cost related to unvested and outstanding WEC Energy Group performance units over the next 1.7 years on a weighted-average basis.
During the first quarter of 2025, performance units held by our employees with an intrinsic value of $0.7 million were settled. The actual tax benefit from the distribution of these awards was $0.1 million. In January 2025, the Compensation Committee also awarded 8,144 WEC Energy Group performance units to our officers and other key employees under its normal schedule of awarding long-term incentive compensation.
Restrictions
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.
In accordance with our most recent rate order, we may not pay common dividends above the test year forecasted amount reflected in our rate case, if it would cause our average common equity ratio, on a financial basis, to fall below our authorized level of 53.0%. A return of capital in excess of the test year amount can be paid by us at the end of the year provided that our average common equity ratio does not fall below the authorized level.
See Note 13, Short-Term Debt and Lines of Credit, for a discussion of certain financial covenants related to our short-term debt obligations.
As of December 31, 2024, our retained earnings were fully restricted. Our equity in undistributed earnings of investees accounted for by the equity method was approximately $11 million.
We do not believe that these restrictions will materially affect our operations or limit any dividend payments in the foreseeable future.
NOTE 12-PREFERRED STOCK
We have 1,000,000 shares of preferred stock with a $100 par value authorized for issuance, of which none were issued and outstanding at December 31, 2024 and 2023.
NOTE 13-SHORT-TERM DEBT AND LINES OF CREDIT
The following table shows our short-term borrowings and their corresponding weighted-average interest rates as of December 31:
(in millions, except percentages) 2024 2023
Commercial paper
Amount outstanding at December 31 $ 62.0 $ 310.3
Average interest rate on amounts outstanding at December 31 4.52 % 5.41 %
Our average amount of commercial paper borrowings based on daily outstanding balances during 2024 was $251.9 million, with a weighted-average interest rate during the period of 5.30%.
We have entered into a bank back-up credit facility to maintain short-term credit liquidity which, among other terms, requires us to maintain, subject to certain exclusions, a total funded debt to capitalization ratio of 65% or less. As of December 31, 2024, we were in compliance with this ratio.
2024 Form 10-K 79
Wisconsin Public Service Corporation
The information in the table below relates to our revolving credit facility used to support our commercial paper borrowing program, including remaining available capacity under this facility as of December 31:
(in millions) Maturity 2024
Revolving credit facility September 2026 $ 400.0
Less:
Letters of credit issued inside credit facility 1.3
Commercial paper outstanding 62.0
Available capacity under existing agreement $ 336.7
This facility has a renewal provision for two extensions, subject to lender approval. Each extension is for a period of one year.
Our bank back-up credit facility contains customary covenants, including certain limitations on our ability to sell assets. The credit facility also contains customary events of default, including payment defaults, material inaccuracy of representations and warranties, covenant defaults, bankruptcy proceedings, certain judgments, Employee Retirement Income Security Act of 1974 defaults and change of control.
NOTE 14-LONG-TERM DEBT
The following table is a summary of our long-term debt outstanding as of December 31:
(in millions) Interest Rate Year Due 2024 2023
Senior Notes (unsecured) 5.35% 2025 $ 300.0 $ 300.0
6.08% 2028 50.0 50.0
4.55% 2029 300.0 -
5.55% 2036 125.0 125.0
3.671% 2042 300.0 300.0
4.752% 2044 450.0 450.0
3.30% 2049 300.0 300.0
2.85% 2051 450.0 450.0
Total 2,275.0 1,975.0
Unamortized debt issuance costs (15.4) (14.5)
Unamortized discount, net (1.6) (1.4)
Total long-term debt, including current portion 2,258.0 1,959.1
Current portion of long-term debt (300.0) -
Total long-term debt $ 1,958.0 $ 1,959.1
We amortize debt premiums, discounts, and debt issuance costs over the life of the debt using the straight-line method and we include the costs in interest expense.
In December 2024, we issued $300.0 million of 4.55% Senior Notes due December 1, 2029, and used the net proceeds to repay short-term debt.
The following table shows the future maturities of our long-term debt outstanding as of December 31, 2024:
(in millions) Payments
2025 $ 300.0
2026 -
2027 -
2028 50.0
2029 300.0
Thereafter 1,625.0
Total $ 2,275.0
2024 Form 10-K 80
Wisconsin Public Service Corporation
Our long-term debt obligations contain covenants related to payment of principal and interest when due and various other obligations. Failure to comply with these covenants could result in an event of default, which could result in the acceleration of outstanding debt obligations.
NOTE 15-LEASES
Obligations Under Finance Leases
In accordance with ASC Subtopic 980-842, Regulated Operations - Leases (Subtopic 980-842), the timing of expense recognition associated with our finance leases is modified to conform to the rate treatment. Amortization of the right-of-use asset is modified so that the total of the imputed interest and amortization costs equals the lease expense that is allowed for rate-making purposes. The difference between this lease expense and the sum of imputed interest and unadjusted amortization costs calculated under Topic 842 is deferred as a regulatory asset on our balance sheets in accordance with Subtopic 980-842.
Land Leases - Utility Solar Generation
We have entered into various land leases related to our investments in utility solar generation. Each lease has an initial term and one or more optional extensions. We expect the optional extensions to be exercised, and, as a result, all of the land leases are being amortized over an extended term of approximately 50 years. Once a solar project achieves commercial operation, the lease liability is remeasured to reflect the final total acres being leased. Our payments related to these leases are being recovered through rates.
Amounts Recognized in the Financial Statements and Other Information
Lease expense and cash payments related to our finance leases were not significant in 2024, 2023, or 2022. Other information related to these leases for the years ended December 31 is as follows:
Other information (dollar amounts in millions)
2024 2023 2022
Non-cash activities:
Right of use assets obtained in exchange for finance lease liabilities (1)
$ 15.5 $ 6.6 $ 10.2
Weighted average remaining lease term 48.8 years 48.4 years 49.0 years
Weighted average discount rate (2)
5.1 % 4.3 % 3.9 %
(1) Amounts are net of any reductions to right of use assets and finance lease liabilities resulting from remeasurements.
(2) Because these leases do not provide an implicit rate of return, we used an estimate of the fully collateralized incremental borrowing rates based upon information available for similarly rated companies in determining the present value of lease payments.
The following table summarizes our finance lease right of use assets and obligations at December 31:
(in millions) 2024 2023 Balance Sheet Location
Right of use assets
Finance lease right of use assets, net (1)
$ 58.2 $ 43.8 Property, plant, and equipment, net
Lease obligations
Long-term finance lease liabilities $ 65.7 $ 49.0 Finance lease obligations
(1) Amounts are net of accumulated amortization of $4.1 million and $3.1 million at December 31, 2024 and 2023, respectively.
2024 Form 10-K 81
Wisconsin Public Service Corporation
Future minimum lease payments under our finance leases and the present value of our net minimum lease payments as of December 31, 2024, were as follows:
(in millions) Total Finance Leases
2025 $ 1.8
2026 1.9
2027 2.5
2028 2.6
2029 2.7
Thereafter 197.9
Total minimum lease payments 209.4
Less: Interest (143.7)
Present value of minimum lease payments 65.7
Less: Short-term lease liabilities -
Long-term lease liabilities $ 65.7
As of February 21, 2025, we have not entered into any material leases that have not yet commenced.
NOTE 16-INCOME TAXES
Income Tax Expense
The following table is a summary of income tax expense for each of the years ended December 31:
(in millions) 2024 2023 2022
Current tax expense (benefit) $ (1.0) $ 17.8 $ 8.7
Deferred income taxes, net 56.2 48.7 66.3
ITCs (3.6) (3.8) (2.8)
Total income tax expense $ 51.6 $ 62.7 $ 72.2
Statutory Rate Reconciliation
The provision for income taxes for each of the years ended December 31 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:
2024 2023 2022
(in millions) Amount Effective Tax Rate Amount Effective Tax Rate Amount Effective Tax Rate
Statutory federal income tax $ 63.9 21.0 % $ 67.8 21.0 % $ 64.5 21.0 %
State income taxes net of federal tax benefit 18.9 6.2 % 20.2 6.3 % 19.5 6.3 %
PTCs, net (17.1) (5.6) % (14.4) (4.5) % (0.6) (0.2) %
Federal excess deferred tax amortization (1)
(5.7) (1.9) % (5.7) (1.8) % (5.2) (1.7) %
Federal excess deferred tax amortization - Wisconsin unprotected (2)
- - % (3.8) (1.2) % (3.8) (1.2) %
ITCs (3.6) (1.2) % (3.8) (1.2) % (2.8) (0.9) %
Other, net (4.8) (1.6) % 2.4 0.8 % 0.6 0.2 %
Total income tax expense $ 51.6 16.9 % $ 62.7 19.4 % $ 72.2 23.5 %
(1) The Tax Cuts and Jobs Act of 2017 required us to remeasure our deferred income taxes and we began to amortize the resulting excess protected deferred income taxes beginning in 2018 in accordance with normalization requirements. The decrease in income tax expense related to the amortization of the deferred tax benefits is offset by a decrease in revenue as the benefits are returned to customers, resulting in no impact on net income.
(2) In accordance with the rate order received from the PSCW in December 2019, we amortized these unprotected deferred tax benefits over periods ranging from two years to four years, to reduce near-term rate impacts to our customers. The decrease in income tax expense related to the amortization of the deferred tax benefits was offset by a decrease in revenue as the benefits were returned to customers, resulting in no impact on net income. This amortization was completed in 2023.
2024 Form 10-K 82
Wisconsin Public Service Corporation
Deferred Income Tax Assets and Liabilities
The components of deferred income taxes as of December 31 were as follows:
(in millions) 2024 2023
Deferred tax assets
Tax gross up - regulatory items $ 89.4 $ 94.8
Future tax benefits 4.8 8.8
Other 21.9 21.3
Total deferred tax assets $ 116.1 $ 124.9
Deferred tax liabilities
Property-related 986.7 935.7
Employee benefits and compensation 70.5 66.7
Other 55.8 46.9
Total deferred tax liabilities 1,113.0 1,049.3
Deferred tax liability, net $ 996.9 $ 924.4
Consistent with ratemaking treatment, deferred taxes in the table above are offset for temporary differences that have related regulatory assets and liabilities.
The components of net deferred tax assets associated with federal tax benefit carryforwards as of December 31, 2024 and 2023 are summarized in the tables below:
2024 (in millions)
Gross Value Deferred Tax Effect Earliest Year of Expiration
Future tax benefits as of December 31, 2024
Federal tax credit $ - $ 4.8 2042
Balance as of December 31, 2024 $ - $ 4.8
2023 (in millions)
Gross Value Deferred Tax Effect Earliest Year of Expiration
Future tax benefits as of December 31, 2023
Federal tax credit $ - $ 8.8 2042
Balance as of December 31, 2023 $ - $ 8.8
Unrecognized Tax Benefits
We had no unrecognized tax benefits at December 31, 2024 and 2023.
We do not expect any unrecognized tax benefits to affect our effective tax rate in periods after December 31, 2024.
For the years ended December 31, 2024, 2023, and 2022, we recognized no interest expense and no penalties related to unrecognized tax benefits in our income statements. At December 31, 2024 and 2023, we had no interest accrued and no penalties accrued related to unrecognized tax benefits on our balance sheets.
We do not anticipate any significant increases in the total amount of unrecognized tax benefits within the next 12 months.
Our primary tax jurisdictions include federal and the state of Wisconsin. With a few exceptions, we are no longer subject to federal income tax examinations by the IRS for years prior to 2021. As of December 31, 2024, we were subject to examination by the Wisconsin taxing authority for tax years 2020 through 2024.
2024 Form 10-K 83
Wisconsin Public Service Corporation
NOTE 17-FAIR VALUE MEASUREMENTS
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:
December 31, 2024
(in millions) Level 1 Level 2 Level 3 Total
Derivative assets
Natural gas contracts $ 3.3 $ 2.8 $ - $ 6.1
FTRs - - 2.0 2.0
Total derivative assets $ 3.3 $ 2.8 $ 2.0 $ 8.1
Derivative liabilities
Natural gas contracts $ 0.6 $ 0.3 $ - $ 0.9
December 31, 2023
(in millions) Level 1 Level 2 Level 3 Total
Derivative assets
Natural gas contracts $ 0.6 $ 1.3 $ - $ 1.9
FTRs - - 2.0 2.0
Coal contracts - 0.3 - 0.3
Total derivative assets $ 0.6 $ 1.6 $ 2.0 $ 4.2
Derivative liabilities
Natural gas contracts $ 7.4 $ 0.5 $ - $ 7.9
Coal contracts - 1.0 - 1.0
Total derivative liabilities $ 7.4 $ 1.5 $ - $ 8.9
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 Markets.
The following table summarizes the changes to derivatives classified as Level 3 in the fair value hierarchy at December 31:
(in millions) 2024 2023 2022
Balance at the beginning of the period $ 2.0 $ 4.1 $ 1.4
Purchases 8.2 6.3 11.7
Settlements (8.2) (8.4) (9.0)
Balance at the end of the period $ 2.0 $ 2.0 $ 4.1
Fair Value of Financial Instruments
The following table shows the financial instruments included on our balance sheets that are not recorded at fair value:
December 31, 2024 December 31, 2023
(in millions) Carrying Amount Fair Value Carrying Amount Fair Value
Long-term debt, including current portion $ 2,258.0 $ 1,882.1 $ 1,959.1 $ 1,662.8
The fair value of our long-term debt is categorized within Level 2 of the fair value hierarchy.
2024 Form 10-K 84
Wisconsin Public Service Corporation
NOTE 18-DERIVATIVE INSTRUMENTS
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 were designated as hedging instruments.
December 31, 2024 December 31, 2023
(in millions) Derivative
Assets Derivative
Liabilities Derivative
Assets Derivative
Liabilities
Current
Natural gas contracts $ 5.8 $ 0.9 $ 1.9 $ 7.4
FTRs 2.0 - 2.0 -
Coal contracts - - 0.3 0.7
Total current 7.8 0.9 4.2 8.1
Long-term
Natural gas contracts 0.3 - - 0.5
Coal contracts - - - 0.3
Total long-term 0.3 - - 0.8
Total $ 8.1 $ 0.9 $ 4.2 $ 8.9
Realized gains and losses on derivatives are primarily recorded in cost of sales upon settlement; however, they may be subsequently deferred for future rate recovery or refund as the gains and losses are included in our fuel and natural gas cost recovery mechanisms. Our estimated notional sales volumes and realized gains and losses were as follows for the years ended:
December 31, 2024 December 31, 2023 December 31, 2022
(in millions) Volumes Gains (Losses) Volumes Gains (Losses) Volumes Gains
Natural gas contracts 43.2 Dth
$ (19.6) 40.6 Dth
$ (52.0) 33.4 Dth
$ 43.1
FTRs 8.6 MWh
2.0 8.3 MWh
10.2 7.8 MWh
2.5
Total $ (17.6) $ (41.8) $ 45.6
At December 31, 2024 and 2023, we had posted cash collateral of $5.7 million and $15.9 million, respectively. We had also received cash collateral of $1.1 million at December 31, 2024.
The following table shows derivative assets and derivative liabilities if derivative instruments by counterparty were presented net on our balance sheets:
December 31, 2024 December 31, 2023
(in millions) Derivative
Assets Derivative
Liabilities Derivative
Assets Derivative
Liabilities
Gross amount recognized on the balance sheet $ 8.1 $ 0.9 $ 4.2 $ 8.9
Gross amount not offset on the balance sheet (1.6) (1)
(0.5) (0.6) (7.5) (2)
Net amount $ 6.5 $ 0.4 $ 3.6 $ 1.4
(1) Includes cash collateral received of $1.1 million.
(2) Includes cash collateral posted of $6.9 million.
NOTE 19-EMPLOYEE BENEFITS
Pension and Other Postretirement Employee Benefits
We have our own noncontributory, qualified pension plan.
We serve as plan sponsor and administrator for certain OPEB plans. The benefits are funded through irrevocable trusts, as allowed for income tax purposes. Our balance sheets reflect only the liabilities associated with our past and current employees and our share
2024 Form 10-K 85
Wisconsin Public Service Corporation
of the plan assets and obligations. WEC Energy Group also offers medical, dental, and life insurance benefits to our active employees and their dependents. We expense the allocated costs of these benefits as incurred.
The defined benefit pension plans are closed to all new hires. In addition, the service accruals for the defined benefit pension plans were frozen for non-union employees as of January 1, 2013. These employees receive an annual company contribution to their 401(k) savings plan, which is calculated based on age, wages, and full years of vesting service as of December 31 each year.
We use a year-end measurement date to measure the funded status of all of the pension and OPEB plans. Due to the regulated nature of our business, we have concluded that substantially all of the unrecognized costs resulting from the recognition of the funded status of the pension and OPEB plans qualify as a regulatory asset.
The following tables provide a reconciliation of the changes in our share of the plans' benefit obligations and fair value of assets:
Pension Benefits OPEB Benefits
(in millions) 2024 2023 2024 2023
Change in benefit obligation
Obligation at January 1 $ 586.7 $ 560.7 $ 128.7 $ 112.2
Service cost 5.0 4.8 3.1 2.8
Interest cost 29.3 30.1 6.6 6.1
Actuarial (gain) loss (34.8) 25.3 0.2 16.7
Participant contributions - - 0.7 0.8
Benefit payments (35.7) (34.2) (9.3) (9.9)
Obligation at December 31 $ 550.5 $ 586.7 $ 130.0 $ 128.7
Change in fair value of plan assets
Fair value at January 1 $ 713.7 $ 685.1 $ 271.9 $ 255.6
Actual return on plan assets 35.1 62.2 17.0 24.5
Employer contributions 0.5 0.6 0.8 0.9
Participant contributions - - 0.7 0.8
Benefit payments (35.7) (34.2) (9.3) (9.9)
Fair value at December 31 $ 713.6 $ 713.7 $ 281.1 $ 271.9
Funded status at December 31 $ 163.1 $ 127.0 $ 151.1 $ 143.2
In 2024, we had actuarial gains related to our pension benefit obligations of $34.8 million and actuarial losses in 2023 of $25.3 million. The primary driver for the actuarial gain was a higher discount rate in 2024. Partially offsetting the gain in 2024, was lower than expected asset returns. The discount rate for our pension benefits was 5.70%, 5.15%, and 5.50% in 2024, 2023, and 2022, respectively.
In 2024 and 2023, we had actuarial losses related to our OPEB benefit obligation of $0.2 million and $16.7 million, respectively, both of which were driven by claims and premium updates and changes to medical trend assumptions. Partially offsetting the losses, was a higher discount rate in 2024. The discount rate for our OPEB benefits was 5.74%, 5.16%, and 5.50% in 2024, 2023, and 2022, respectively.
The amounts recognized on our balance sheets at December 31 related to the funded status of the benefit plans were as follows:
Pension Benefits OPEB Benefits
(in millions) 2024 2023 2024 2023
Pension and OPEB assets $ 167.3 $ 131.6 $ 161.6 $ 152.9
Other long-term liabilities 4.2 4.6 10.5 9.7
Total net assets $ 163.1 $ 127.0 $ 151.1 $ 143.2
The accumulated benefit obligation for the defined benefit pension plans was $521.7 million and $548.1 million at December 31, 2024 and 2023, respectively.
2024 Form 10-K 86
Wisconsin Public Service Corporation
The following table shows information for pension plans with an accumulated benefit obligation in excess of plan assets. There were no plan assets related to these pension plans. Amounts presented are as of December 31:
(in millions) 2024 2023
Accumulated benefit obligation $ 4.2 $ 4.7
The following table shows information for pension plans with a projected benefit obligation in excess of plan assets. There were no plan assets related to these pension plans. Amounts presented are as of December 31:
(in millions) 2024 2023
Projected benefit obligation $ 4.2 $ 4.7
The following table shows information for OPEB plans with an accumulated benefit obligation in excess of plan assets. Amounts presented are as of December 31:
(in millions) 2024 2023
Accumulated benefit obligation $ 15.0 $ 14.5
Fair value of plan assets 4.4 4.8
The following table shows the amounts that had not yet been recognized in our net periodic benefit cost as of December 31:
Pension Benefits OPEB Benefits
(in millions) 2024 2023 2024 2023
Net regulatory assets (liabilities)
Net actuarial loss (gain) $ 17.0 $ 53.2 $ (29.8) $ (28.1)
Prior service credits - - (10.8) (21.0)
Total $ 17.0 $ 53.2 $ (40.6) $ (49.1)
The components of net periodic benefit cost (credit) (including amounts capitalized to our balance sheets) for the years ended December 31 were as follows:
Pension Benefits OPEB Benefits
(in millions) 2024 2023 2022 2024 2023 2022
Service cost $ 5.0 $ 4.8 $ 9.0 $ 3.1 $ 2.8 $ 4.0
Interest cost 29.3 30.1 22.7 6.6 6.1 4.4
Expected return on plan assets (51.1) (51.3) (55.2) (17.3) (16.3) (21.0)
Amortization of prior service credit - - - (10.2) (10.2) (10.2)
Amortization of net actuarial loss (gain) 17.3 17.3 17.3 2.4 1.0 (2.5)
Net periodic benefit cost (credit) $ 0.5 $ 0.9 $ (6.2) $ (15.4) $ (16.6) $ (25.3)
Effective January 1, 2023, the PSCW approved escrow accounting for pension and OPEB costs. As a result, as of December 31, 2024 and 2023, we recorded a $12.9 million and a $6.7 million regulatory asset for pension costs, respectively, and a $14.6 million and a $6.8 million regulatory asset for OPEB costs, respectively. The above table does not reflect any adjustments for the creation of these regulatory assets.
2024 Form 10-K 87
Wisconsin Public Service Corporation
The weighted-average assumptions used to determine the benefit obligations for the plans were as follows for the years ended December 31:
Pension Benefits OPEB Benefits
2024 2023 2024 2023
Discount rate 5.70% 5.15% 5.74% 5.16%
Rate of compensation increase 4.00% 4.00% N/A N/A
Interest credit rate 4.50% 4.50% N/A N/A
Assumed medical cost trend rate (Pre 65) N/A N/A 7.00% 6.25%
Ultimate trend rate (Pre 65) N/A N/A 5.00% 5.00%
Year ultimate trend rate is reached (Pre 65) N/A N/A 2033 2031
Assumed medical cost trend rate (Post 65) N/A N/A 6.00% 6.25%
Ultimate trend rate (Post 65) N/A N/A 5.00% 5.00%
Year ultimate trend rate is reached (Post 65) N/A N/A 2030 2030
The weighted-average assumptions used to determine net periodic benefit cost for the plans were as follows for the years ended December 31:
Pension Benefits
2024 2023 2022
Discount rate 5.15% 5.50% 3.00%
Expected return on plan assets 6.75% 6.75% 7.00%
Rate of compensation increase 4.00% 4.00% 4.00%
Interest credit rate 4.50% 4.00% 2.25%
OPEB Benefits
2024 2023 2022
Discount rate 5.16% 5.50% 2.98%
Expected return on plan assets 6.50% 6.50% 7.00%
Assumed medical cost trend rate (Pre 65) 6.25% 6.50% 5.70%
Ultimate trend rate (Pre 65) 5.00% 5.00% 5.00%
Year ultimate trend rate is reached (Pre 65) 2031 2031 2028
Assumed medical cost trend rate (Post 65) 6.25% 6.00% 5.60%
Ultimate trend rate (Post 65) 5.00% 5.00% 5.00%
Year ultimate trend rate is reached (Post 65) 2030 2031 2028
WEC Energy Group consults with its investment advisors on an annual basis to help forecast expected long-term returns on plan assets by reviewing historical returns as well as calculating expected total trust returns using the weighted-average of long-term market returns for each of the major target asset categories utilized in the trust. For 2025, the expected return on asset assumption is 6.75% for the pension plan and 6.50% for the OPEB plan.
Plan Assets
Current pension trust assets and amounts which are expected to be contributed to the trusts in the future are expected to be adequate to meet pension payment obligations to current and future retirees.
The Investment Trust Policy Committee oversees investment matters related to all of our funded benefit plans. The Committee works with external actuaries and investment consultants on an on-going basis to establish and monitor investment strategies and target asset allocations. Forecasted cash flows for plan liabilities are regularly updated based on annual valuation results. Target allocations are determined utilizing projected benefit payment cash flows and risk analyses of appropriate investments. They are intended to reduce risk, provide long-term financial stability for the plans and maintain funded levels which meet long-term plan obligations while preserving sufficient liquidity for near-term benefit payments.
Our pension trust target asset allocations are 25% equity investments, 55% fixed income investments, and 20% private equity and real estate investments. The OPEB trust has a target asset allocation of 45% equity investments, 45% fixed income investments, and 10% real estate investments. Equity securities include investments in large-cap, mid-cap, and small-cap companies. Fixed income
2024 Form 10-K 88
Wisconsin Public Service Corporation
securities include corporate bonds of companies from diversified industries, mortgage and other asset backed securities, commercial paper, and United States Treasuries.
Pension and OPEB plan investments are recorded at fair value. See Note 1(o), Fair Value Measurements, for more information regarding the fair value hierarchy and the classification of fair value measurements based on the types of inputs used.
The following tables provide the fair values of our investments by asset class:
December 31, 2024
Pension Plan Assets OPEB Assets
(in millions) Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total
Asset Class
Equity securities:
United States equity $ 47.9 $ - $ - $ 47.9 $ 33.3 $ - $ - $ 33.3
International equity 45.0 - - 45.0 30.7 - - 30.7
Fixed income securities: (1)
United States bonds - 172.4 - 172.4 36.5 63.9 - 100.4
International bonds - 22.3 - 22.3 - 2.9 - 2.9
$ 92.9 $ 194.7 $ - $ 287.6 $ 100.5 $ 66.8 $ - $ 167.3
Investments measured at net asset value:
Equity securities 117.3 66.4
Fixed income securities 67.9 18.8
Other 240.8 28.6
Total $ 713.6 $ 281.1
(1) This category represents investment grade bonds of United States and foreign issuers denominated in United States dollars from diverse industries.
December 31, 2023
Pension Plan Assets OPEB Assets
(in millions) Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total
Asset Class
Equity securities:
United States equity $ 52.0 $ - $ - $ 52.0 $ 32.6 $ - $ - $ 32.6
International equity 53.7 - - 53.7 29.8 - - 29.8
Fixed income securities: (1)
United States bonds - 176.7 - 176.7 33.9 61.3 - 95.2
International bonds - 22.8 - 22.8 - 2.9 - 2.9
$ 105.7 $ 199.5 $ - $ 305.2 $ 96.3 $ 64.2 $ - $ 160.5
Investments measured at net asset value:
Equity securities 112.5 65.1
Fixed income securities 66.1 17.1
Other 229.9 29.2
Total $ 713.7 $ 271.9
(1) This category represents investment grade bonds of United States and foreign issuers denominated in United States dollars from diverse industries.
Cash Flows
We expect to contribute $0.5 million to the pension plans and $1.0 million to the OPEB plans in 2025, dependent upon various factors affecting us, including our liquidity position and possible tax law changes.
2024 Form 10-K 89
Wisconsin Public Service Corporation
The following table shows the payments, reflecting expected future service, that we expect to make for pension and OPEB over the next 10 years:
(in millions) Pension Benefits OPEB Benefits
2025 $ 38.2 $ 9.3
2026 38.3 9.8
2027 38.8 10.2
2028 39.0 10.4
2029 38.7 10.5
2030-2034 192.5 51.7
Savings Plans
WEC Energy Group sponsors 401(k) savings plans that allow substantially all of our full-time employees to contribute a portion of their pre-tax and/or after-tax income in accordance with plan-specified guidelines. A percentage of employee contributions are matched by us through a contribution into the employee's savings plan account, up to certain limits. The 401(k) savings plans include an Employee Stock Ownership Plan. Certain employees receive an employer retirement contribution, which amounts are contributed to an employee's savings plan account based on the employee's wages, age, and years of service. Total costs incurred under all of these plans were $13.8 million, $12.8 million, and $11.7 million in 2024, 2023, and 2022, respectively.
NOTE 20-SEGMENT INFORMATION
Our President, who is our CODM, reviews financial information presented on a segment basis for purposes of making operating decisions and assessing performance. The CODM regularly reviews net income to measure segment profitability and to allocate resources, including assets, to our business. Net income best measures our segment profitability as it reflects all revenues and costs, including the impact on our tax provision from tax credits generated through investments in renewable generation facilities.
Our CODM allocates resources such as employees as well as financial and capital resources to our segments during the annual review of budgets and the capital plan. Our CODM also reviews and revises the resources throughout the year during the monthly forecasting process in order to make timely decisions that align with our overall corporate strategy. The CODM uses each segment’s net income to evaluate performance by comparing actual results to budgeted and forecasted amounts, as well as the ROE earned.
Segments were determined based on a combination of factors, including the regulatory environment of each geographical jurisdiction in which the segment operates, equity investment interests, as well as the revenue streams for the products or services provided to customers through electric and natural gas operations. See Note 4, Operating Revenues, for more information on disaggregation of operating revenues. The accounting policies of the segments are the same as those described in Note 1, Summary of Significant Accounting Policies.
At December 31, 2024, we reported two segments, which are described below. All of our operations are located within the United States.
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 WRPC.
2024 Form 10-K 90
Wisconsin Public Service Corporation
The following tables show summarized financial information related to our reportable segments for the years ended December 31, 2024, 2023, and 2022.
2024 (in millions)
Utility Other Wisconsin Public Service Corporation
External revenues $ 1,560.4 $ - $ 1,560.4
Fuel and purchased power
321.5 - 321.5
Cost of natural gas sold
163.8 - 163.8
Other operation and maintenance 440.3 - 440.3
Depreciation and amortization 238.5 - 238.5
Property and revenue taxes
46.9 - 46.9
Other income, net (1)
48.2 1.9 50.1
Interest expense 95.0 - 95.0
Income tax expense 51.2 0.4 51.6
Net income $ 251.4 $ 1.5 $ 252.9
Other Segment Disclosures
Capital expenditures and asset acquisitions
$ 495.9 $ - $ 495.9
Equity method investments
0.9 14.9 15.8
Total assets 7,480.8 14.9 7,495.7
(1)Includes equity earnings from equity method investments of $1.9 million included in the other segment, as well as amounts that are not material for interest income.
2023 (in millions)
Utility Other Wisconsin Public Service Corporation
External revenues $ 1,681.4 $ - $ 1,681.4
Fuel and purchased power
388.1 - 388.1
Cost of natural gas sold
218.7 - 218.7
Other operation and maintenance 434.3 - 434.3
Depreciation and amortization 226.9 - 226.9
Property and revenue taxes
47.4 - 47.4
Other income, net (1)
43.8 2.1 45.9
Interest expense 89.0 - 89.0
Income tax expense 62.3 0.4 62.7
Net income $ 258.5 $ 1.7 $ 260.2
Other Segment Disclosures
Capital expenditures and asset acquisitions
$ 635.6 $ - $ 635.6
Equity method investments
0.8 13.6 14.4
Total assets 7,017.5 13.6 7,031.1
(1)Includes equity earnings from equity method investments of $2.1 million included in the other segment, as well as amounts that are not material for interest income.
2024 Form 10-K 91
Wisconsin Public Service Corporation
2022 (in millions)
Utility Other Wisconsin Public Service Corporation
External revenues $ 1,785.2 $ - $ 1,785.2
Fuel and purchased power
515.5 - 515.5
Cost of natural gas sold
329.6 - 329.6
Other operation and maintenance 362.5 - 362.5
Depreciation and amortization 199.8 - 199.8
Property and revenue taxes
42.4 - 42.4
Other income, net (1)
41.0 1.3 42.3
Interest expense 70.5 - 70.5
Income tax expense 71.9 0.3 72.2
Net income $ 234.0 $ 1.0 $ 235.0
Other Segment Disclosures
Capital expenditures $ 433.8 $ - $ 433.8
Equity method investments
0.8 12.8 13.6
Total assets 6,696.0 12.8 6,708.8
(1)Includes equity earnings from equity method investments of $1.3 million included in the other segment, as well as amounts that are not material for interest income.
NOTE 21-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.
The following table shows our minimum future commitments related to these purchase obligations as of December 31, 2024:
Payments Due By Period
(in millions) Date Contracts Extend Through Total Amounts Committed 2025 2026 2027 2028 2029 Later Years
Electric utility:
Purchased power 2063 $ 263.0 $ 56.1 $ 57.2 $ 51.8 $ 47.9 $ 21.1 $ 28.9
Coal supply and transportation 2026 101.1 89.1 12.0 - - - -
Other 2043 80.2 10.0 10.1 8.7 7.1 6.3 38.0
Natural gas utility supply and transportation 2048 615.7 59.4 57.5 57.3 56.0 49.8 335.7
Total $ 1,060.0 $ 214.6 $ 136.8 $ 117.8 $ 111.0 $ 77.2 $ 402.6
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 SO2, NOx, fine particulates, ozone, 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.
2024 Form 10-K 92
Wisconsin Public Service Corporation
We have continued to pursue a proactive strategy to manage our environmental compliance obligations, including:
•the development of additional sources of renewable electric energy supply, battery storage, and natural gas storage facilities;
•the addition of improvements for water quality matters such as treatment technologies to meet regulatory discharge limits and improvements to our cooling water intake systems;
•the addition of emission control equipment to existing facilities to comply with ambient air quality standards and federal clean air rules;
•the protection of wetlands and waterways, biodiversity including threatened and endangered species, and cultural resources associated with construction projects;
•the retirement of older coal-fired power plants and conversion to modern, efficient, natural gas generation, and/or replacement with renewable generation;
•the beneficial use of ash and other products from coal-fired generating units;
•the remediation of former manufactured gas plant sites;
•the reduction of methane emissions across our natural gas distribution system by upgrading infrastructure; and
•the tracking and reporting of GHG emissions to comply with federal clean air rules.
Air Quality
Cross State Air Pollution Rule - Good Neighbor Rule
In March 2023, the EPA issued its final Good Neighbor Rule, 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 we are well positioned to meet the requirements.
Our RICE units 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.
In February 2024, the Supreme Court heard oral arguments regarding stay applications related to the EPA's Good Neighbor Rule. In June 2024, the Supreme Court granted a stay of the Good Neighbor Rule pending disposition of the applicants' petitions for review at the D.C. Circuit Court of Appeals. The D.C. Circuit Court of Appeals litigation has been held in abeyance since September 2024, when the court granted the EPA's motion for partial voluntary remand so that it could address issues of severability raised in the Supreme Court's June 2024 opinion granting the petitions for stay of the rule. Pursuant to an order of the D.C. Circuit Court of Appeals, the parties filed motions to govern future proceedings in December 2024. In January 2025, the D.C. Circuit Court of Appeals issued an order returning the consolidated cases to the court's active docket and establishing a schedule for supplemental briefing on the issue of severability that extends through early March 2025. We will continue to monitor this case as arguments at the D.C. Circuit Court of Appeals move forward.
In November 2024, the EPA issued a Good Neighbor Interim Final Rule that administratively stayed the effectiveness of the Good Neighbor Rule in all states to which it originally applies and ensured implementation of good neighbor obligations previously established to address the 2008 ozone NAAQS while the process works through the courts. We are well positioned to comply with the rule's requirements.
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. In May 2024, the EPA published a final rule in the Federal Register lowering the PM limit from 0.03 lb/MMBtu to 0.01 lb/MMBtu. We are well positioned to comply with the rule's requirements.
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
2024 Form 10-K 93
Wisconsin Public Service Corporation
EPA's 2022 CASAC Ozone Review Panel issued a draft report supporting reconsideration of the 2015 standard. The EPA staff initially issued a draft Policy Assessment in March 2023 that also supported the reconsideration; however, in August 2023, the EPA announced that it was instead restarting its ozone standard evaluation. The EPA released the first two volumes of its Integrated Review Plan in December 2024. This new review is anticipated to take 3 to 5 years to complete.
Particulate Matter
All counties within our service territory are in attainment with the current 2012 standards for fine PM2.5. Under the Biden Administration's policy review, the EPA concluded that the scientific evidence and information from a December 2020 review of the 2012 standards supported revising the level of the annual standard for the PM2.5 NAAQS to below the current level of 12 µg/m3, while retaining the 24-hour standard of 35 µg/m3. In February 2024, the EPA finalized a rule which lowered the primary (health-based) annual PM2.5 NAAQS to 9 µg/m3. The secondary (welfare-based) PM2.5 standard and 24-hour standards (both primary and secondary) remain unchanged. The EPA has until February 2026 to designate areas as attainment and nonattainment with the new standard. The WDNR will need to draft and submit a state implementation plan for the EPA's approval. A designation of nonattainment status could impact future permitting activities for facilities in applicable locations, including the potential need for improved or new air pollution control equipment. With our planned transition from coal-fired plants to natural gas-fired plants and renewable generating facilities, we do not expect this new standard to have a material impact on our units.
Climate Change
In May 2023, the EPA proposed GHG performance standards for fossil-fired steam generating and natural gas combustion units and also proposed to repeal the Affordable Clean Energy rule, which had replaced the Clean Power Plan. The final rule, known as the Greenhouse Gas Power Plant Rule, was published in May 2024. Pursuant to the final rule, there are no applicable standards for coal plants until the end of 2031 and after 2031, the applicable standard is dependent upon the unit's retirement date. Coal-fired units that are planned to refuel to natural gas-fired units must convert to natural gas and no longer retain the capability to burn coal by the end of 2029. For new combined cycle natural gas plants above a 40% capacity factor, the rule is dependent upon the implementation of carbon capture by the end of 2031. For new simple cycle natural gas-fired combustion turbines, there are no applicable limits as long as the capacity factor is less than 20%. Our new Weston RICE units are not affected under the rule because the rule excludes RICE units that are less than 25 MWs. Numerous parties have challenged the Greenhouse Gas Power Plant Rule through litigation pending in the D.C. Circuit Court of Appeals.
In March 2024, the EPA announced it had removed regulations on existing natural gas combustion turbines from the rule. At that time, the EPA indicated it would work on new rulemaking phases, focusing on CO2 emissions, as well as NOx and hazardous air pollutants (formaldehyde) emissions. In November 2024, the EPA released the first proposed rule of the three rule "packages" to address NOx emissions from existing combustion turbines. The proposed rule for turbines that operate at a greater than 20% capacity factor, will require more stringent NOx limits and control requirements for new, modified, or reconstructed turbines. For turbines that operate at a capacity of 20% or lower, less restrictive standards and the use of combustion controls would apply. Our combined cycle facilities are well positioned to comply with the proposed rule. As the EPA will not finalize this proposal until late 2025, it could be revised or repealed under the new presidential administration.
In April 2024, the EPA issued its final Mandatory Greenhouse Gas Reporting Rule, 40 CFR Part 98, which includes updates to the global warming potentials to determine CO2 equivalency for threshold reporting and the addition of a new section regarding energy consumption. The revisions will impact the reporting required for our electric generation facilities, LDCs, and underground natural gas storage facilities. In May 2024, the EPA also issued its final rule to amend reporting requirements for petroleum and natural gas systems. Under the final rule, new leak emission factors and reporting requirements for large release events will impact the reporting required for our LDCs and underground natural gas storage facilities.
WEC Energy Group's capital plan includes the retirement of older, fossil-fueled generation, to be replaced with zero-carbon-emitting renewables and reliable, efficient natural gas-fueled generation. We have already retired approximately 400 MWs of fossil-fueled generation since the beginning of 2018, which includes the 2018 retirements of the Pulliam power plant and the jointly-owned Edgewater Unit 4 generating unit. WEC Energy Group expects to retire approximately 1,200 MWs of additional coal-fired generation by the end of 2031, which includes the planned retirement of the jointly-owned Columbia Units 1 and 2 while investigating conversion of at least one unit to natural gas, and the planned retirement of Weston Unit 3. See Note 7, Property, Plant, and Equipment, for more information related to the planned retirement of Columbia Units 1 and 2. In May 2021, WEC Energy Group announced goals to achieve reductions in carbon emissions from its electric generation fleet, which includes us, 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 continuing to make operating refinements, retiring less efficient generating units, and executing its capital plan. Over the longer term, the
2024 Form 10-K 94
Wisconsin Public Service Corporation
target for WEC Energy Group's generation fleet is to be net carbon neutral by 2050. WEC Energy Group also believes it will be in a position to eliminate coal as an energy source by the end of 2032.
WEC Energy Group will also continue to focus on methane emissions reductions by improving its natural gas distribution systems, and have set a target across its natural gas distribution operations, including our 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 continuous operational improvements and equipment upgrades, as well as the use of RNG throughout its natural gas utility distribution systems. In addition, subject to regulatory approval and market conditions, WEC Energy Group expects to procure RTCs.
Water Quality
Clean Water Act Cooling Water Intake Structure Rule
Section 316(b) of the CWA 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.
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 a final BTA determination for Weston Units 3 and 4. In accordance with the requirements in the CWA, the WDNR reissued the Weston WPDES permit in June 2024 (effective July 1, 2024) that includes a determination that existing technology (wet cooling towers) installed at the units represents BTA for minimizing adverse environmental impacts.
Steam Electric Effluent Limitation Guidelines
The EPA's 2015 final ELG rule, which took effect in January 2016 (2015 ELG rule), was modified in 2020 (2020 ELG rule), and again in 2024 with the May 2024 publication of the Supplemental ELG Rule. These rules establish federal technology-based requirements for several types of power plant wastewaters. The two requirements that affect our facilities relate to discharge limits for BATW and CRL (landfill leachate). Although our coal-fueled facilities were constructed with advanced wastewater treatment technologies that meet many of the discharge limits established by the 2015 rule, facility modifications were still necessary at Weston to meet all of the 2015 ELG requirements and the additional ones established by the 2020 ELG rule. Through 2023, compliance costs associated with the 2015 and 2020 ELG rules required $8 million in capital investment.
The 2024 Supplemental ELG rule established zero discharge requirements for BATW and CRL wastewaters at coal-fueled units with no planned retirement date. The Supplemental ELG Rule also kept one existing and created one new “permanent cessation of coal” subcategory. Those electing to cease coal combustion by either retiring or repowering a unit by December 31, 2028 or December 31, 2034 can limit ELG-related capital investments to what was required by either the 2015 or the 2020 ELG Rule, respectively. For units where cessation of coal is planned to occur no later than December 31, 2034, facility owners must complete all 2020 ELG rule required capital investments by December 31, 2025. All of our coal-fueled units fully meet the 2020 ELG rule requirements. Based on current electrical generation resource planning, we plan to file a Notice of Planned Participation by December 31, 2025 to opt into the "cessation of coal by December 31, 2034" subcategory for the Weston coal-fired facilities.
The final Supplemental ELG Rule allows owners of coal-fired units who opted into a cessation of coal subcategory to operate beyond the end of 2028 or 2034, required by either the 2015 or the 2020 ELG Rule, respectively, if needed for reliability concerns (i.e., energy emergencies, reliability must run agreements, etc.) as determined by the DOE, a public utility commission, or independent system operator.
We are still evaluating the Supplemental ELG Rule CRL provisions to determine the applicability and potential compliance costs for inactive/closed landfills. Numerous parties have challenged the rule through litigation pending in the U.S. Court of Appeals for the 8th Circuit. This rule remains in effect during the pendency of the legal challenge.
2024 Form 10-K 95
Wisconsin Public Service Corporation
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 as of December 31:
(in millions) 2024 2023
Regulatory assets $ 114.0 $ 121.5
Reserves for future environmental remediation 77.3 85.3
Coal Combustion Residuals Rule
The EPA finalized a rule for CCR in April 2024 that would apply to landfills, historic fill sites, and projects where CCR was placed at a power plant site. The rule will regulate previously exempt closed landfills.
The final rule, which became effective in November 2024, will have an impact on some of our coal ash landfills, requiring additional remediation that is not currently required under the state programs. The rule is being challenged through litigation pending in the D.C. Circuit Court of Appeals. We expect the cost of the additional remediation would be recovered through future rates. See Note 9, Asset Retirement Obligations, for more information on the estimated cost of the additional remediation.
Renewables, Efficiency, and Conservation
Wisconsin Legislation
In 2005, Wisconsin enacted Act 141, which established a goal that 10% of all electricity consumed in Wisconsin be generated by renewable resources annually. We have achieved our required renewable energy percentage of 9.74% by constructing various wind parks, solar parks, and by also relying on renewable energy purchases. We continue to review our renewable energy portfolio and acquire cost-effective renewables as needed to meet our requirements on an ongoing basis. The PSCW administers the renewable program related to Act 141, and we fund the program, along with other utilities, based on 1.2% of our annual retail operating revenues.
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.
2024 Form 10-K 96
Wisconsin Public Service Corporation
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. See Note 6, Regulatory Assets and Liabilities, for more information about the retirement. Following our significant engagement with the EPA, the agency conditionally terminated the Consent Decree in December 2024.
Joint Ownership Power Plants - Columbia and Edgewater
In December 2009, the EPA issued an NOV to WPL, the operator of the Columbia and Edgewater plants, and the other joint owners of these plants, including MG&E, 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 WPL, MG&E, and 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 Western District of Wisconsin in June 2013. As a result of the continued implementation of the Consent Decree related to the jointly owned Columbia and Edgewater plants, the Edgewater Unit 4 generating unit was retired in September 2018. See Note 6, Regulatory Assets and Liabilities, for more information about the retirement. WPL started the process to close out this Consent Decree.
NOTE 22-SUPPLEMENTAL CASH FLOW INFORMATION
Non-Cash Transactions
Year Ended December 31
(in millions) 2024 2023 2022
Cash paid for interest, net of amount capitalized $ 92.4 $ 87.6 $ 67.8
Cash paid for income taxes, net (1)
8.8 2.9 25.9
Significant non-cash investing and financing transactions:
Accounts payable related to construction costs 50.9 24.8 30.3
Increase in receivable for corporate-owned life insurance proceeds 5.6 - -
Liabilities accrued for software licensing agreements 0.2 - 1.5
(1) Cash paid for income taxes in 2024 and 2023 was net of $22.7 million and $4.9 million, respectively, related to 2023 and 2024 PTCs that were sold to third parties.
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 at December 31 to the total of these amounts shown on the statements of cash flows:
(in millions) 2024 2023 2022
Cash and cash equivalents $ 1.5 $ 1.4 $ 0.5
Restricted cash included in other long-term assets - - 38.0
Cash, cash equivalents, and restricted cash $ 1.5 $ 1.4 $ 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 at December 31, 2022. See Note 2, Acquisitions, for more information on the purchase of this facility.
2024 Form 10-K 97
Wisconsin Public Service Corporation
NOTE 23-REGULATORY ENVIRONMENT
2025 and 2026 Rates
In April 2024, we filed a request with the PSCW to increase our retail electric and natural gas rates. The primary drivers of the requested increases in electric rates were continued capital investments to transition our generation fleet from coal to renewables and natural gas-fueled generation, increased costs driven by higher inflation and interest rates, and the recovery of regulatory assets previously approved by the PSCW. The requested increases in natural gas rates were driven by our ongoing capital investments in reliability and safety projects, as well as the impacts from higher inflation and increased interest rates.
On December 19, 2024, the PSCW issued a final written order approving electric and natural gas base rate increases, effective January 1, 2025 and 2026, as applicable. The final written order reflected the following:
2025 rate increase
Electric (1)
$ 55.1 million / 4.5%
Gas $ 14.9 million / 3.8%
2026 rate increase (2)
Electric (1)
$ 30.0 million / 2.3%
Gas $ 13.5 million / 3.1%
ROE 9.8%
Common equity component average on a financial basis 53.0%
(1) Amounts reflect the impact to our Wisconsin retail electric operations and include the incremental decrease resulting from updated fuel costs.
(2) The 2026 rate increases are incremental to the previously authorized revenue plus the approved rate increases for 2025.
We are required to maintain our current earnings sharing mechanism. Under the current mechanism, if we earn above our authorized ROE: (i) we retain 100.0% of earnings for the first 15 basis points above the authorized ROE; (ii) 50.0% of the next 60 basis points is required to be refunded to ratepayers; and (iii) 100.0% of any remaining excess earnings is required to be refunded to ratepayers.
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 reflected updated fuel costs and revenue requirements for the generation projects that were previously approved by the PSCW and were placed into service in 2023 or were expected to be placed into service in 2024.
In December 2023, the PSCW issued a final written order approving an electric rate decrease of $32.7 million (2.6%) for our Wisconsin retail electric operations, effective January 1, 2024. This amount includes the incremental decrease to our revenue requirements resulting from updated fuel costs.
Our ROE and common equity component average were not addressed in the limited rate case re-opener.
2023 and 2024 Rates
In April 2022, we filed a request with the PSCW to increase our retail electric and natural gas rates. Our request was updated in July 2022 to reflect new developments that impacted the original proposal. The requested increase in electric rates was driven by capital investments in new wind, solar, and battery storage; capital investments in natural gas generation; and changes in wholesale business with other utilities. Many of these investments had already been approved by the PSCW. The requested increase in natural gas rates primarily related to capital investments that had been made to maintain and improve safety and reliability.
2024 Form 10-K 98
Wisconsin Public Service Corporation
In December 2022, the PSCW issued a final written order approving electric and natural gas base rate increases, effective January 1, 2023. The final order reflected the following:
2023 base rate increase
Electric $ 120.5 million / 9.8%
Gas $ 26.4 million / 7.1%
ROE 9.8%
Common equity component average on a financial basis 53.0%
In addition to the above, the final order included the following terms:
•We kept our then current earnings sharing mechanism, under which, if we earned above our authorized ROE: (i) we retained 100.0% of earnings for the first 15 basis points above the authorized ROE; (ii) 50.0% of the next 60 basis points was refunded to ratepayers; and (iii) 100.0% of any remaining excess earnings was required to be refunded to ratepayers.
•We were required to complete an analysis of alternative recovery scenarios for generating units that will be retired prior to the end of their useful life.
•We were not allowed to propose any changes to our real time pricing rates for large commercial and industrial electric customers through the end of 2024.
•We were required to lower monthly residential and small commercial electric customer fixed charges by $3.33 from previously authorized rates.
•We were required to offer an additional voluntary renewable energy pilot for commercial and industrial customers.
•We were required to continue to work with PSCW staff and other interested parties to develop alternative low income assistance programs. We, along with WE, also collectively contributed $4.0 million to the Keep Wisconsin Warm Fund.
•We were required to implement escrow accounting treatment for pension and OPEB costs in 2023 and 2024. As a result, we defer as a regulatory asset or liability, the difference between actual pension and OPEB costs and those included in rates until recovery or refund is authorized in a future rate proceeding.
•As discussed above, we were authorized to file a limited electric rate case re-opener for 2024.
2022 Rates
In March 2021, we filed an application with the PSCW for the approval of certain accounting treatments that allowed us to maintain our electric and natural gas base rates through 2022 and forego filing a rate case for one year. In connection with the request, we also entered into an agreement, dated March 23, 2021, with various stakeholders. Pursuant to the terms of the agreement, the stakeholders fully supported the application. In September 2021, the PSCW issued a written order approving the application.
The final order reflected the following:
•We amortized, in 2022, certain previously deferred balances to offset approximately half of our forecasted revenue deficiency.
•We were able to defer any increases in tax expense due to changes in tax law that occurred in 2021 and/or 2022.
•We maintained our earnings sharing mechanism, with modification.
NOTE 24-OTHER INCOME, NET
Total other income, net was as follows for the years ended December 31:
(in millions) 2024 2023 2022
Non-service components of net periodic benefit costs $ 36.7 $ 35.4 $ 35.3
AFUDC-Equity 9.2 7.6 5.8
Earnings from equity method investments 1.9 2.1 1.3
Other, net 2.3 0.8 (0.1)
Other income, net $ 50.1 $ 45.9 $ 42.3
2024 Form 10-K 99
Wisconsin Public Service Corporation
NOTE 25-NEW ACCOUNTING PRONOUNCEMENTS
Disaggregation of Income Statement Expenses
In November 2024, the FASB issued ASU No. 2024-03, Income Statement-Reporting Comprehensive Income-Expense Disaggregation Disclosures (Subtopic 220-40) Disaggregation of Income Statement Expenses. The amendments require disclosure of certain costs and expenses in the notes to financial statements, which are disaggregated from relevant expense captions on the income statement. The amendments also require additional qualitative disclosures of the amounts remaining in relevant expense captions that are not separately disaggregated quantitatively. Finally, the amendments require disclosure of the total amount of selling expenses and, in annual reporting periods, an entity's definition of selling expenses. The amendments are effective for annual periods beginning after December 15, 2026, and interim periods beginning after December 15, 2027, with early adoption permitted. We plan to adopt these amendments beginning with our fiscal year ending on December 31, 2027, and are currently evaluating the impact this guidance may have on our financial statements and related disclosures.
Improvements to Income Tax Disclosures
In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740): Improvements to Income Tax Disclosures. The amendments require additional disclosures, primarily related to income taxes paid and the rate reconciliation table. The amendments require disclosures on specific categories in the rate reconciliation table, as well as additional information for reconciling items that meet a quantitative threshold. For income taxes paid, additional disclosures are required to disaggregate federal, state, and foreign income taxes paid, with additional disclosures for income taxes paid that meet a quantitative threshold. The amendments are effective for annual periods beginning after December 15, 2024, with early adoption permitted. We plan to adopt these amendments beginning with our fiscal year ending on December 31, 2025, and are currently evaluating the impact this guidance may have on our financial statements and related disclosures.
Improvements to Reportable Segment Disclosures
In November 2023, the FASB issued ASU No. 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures. The amendments require additional disclosures about reportable segments on an annual and interim basis. The amendments require disclosure of significant segment expenses that are (1) regularly provided to the CODM and (2) included in the reported measure of segment profit or loss. The amendments also require disclosure of an amount for other segment items and a description of its composition. The new standard also allows companies to disclose multiple measures of segment profit or loss if those measures are used to assess performance and allocate resources. The update was effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024, with early adoption permitted. We adopted these amendments beginning with our fiscal year ending on December 31, 2024. See Note 20, Segment Information, which reflects the implementation of this update in our disclosures about our reportable segments.
2024 Form 10-K 100
Wisconsin Public Service Corporation

---

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
None.

---

ITEM 9A. CONTROLS AND PROCEDURES
ITEM 9A. CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
Our management, with the participation of our principal executive officer and principal financial officer, has evaluated the effectiveness of our disclosure controls and procedures (as such term is defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this report. Based upon such evaluation, our principal executive officer and principal financial officer have concluded that, as of the end of such period, our disclosure controls and procedures are effective: (i) in recording, processing, summarizing and reporting, on a timely basis, information required to be disclosed by us in the reports that we file or submit under the Exchange Act; and (ii) to ensure that information required to be disclosed in the reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and principal financial officer, to allow timely decisions regarding required disclosure.
Management's Report on Internal Control Over Financial Reporting
Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rules 13a-15(f) and 15d-15(f). Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on its evaluation, our management concluded that our internal control over financial reporting was effective as of December 31, 2024.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation. Also, projections of any evaluation of the effectiveness of internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
This Annual Report on Form 10-K does not include an attestation report of our independent registered public accounting firm regarding internal control over financial reporting. Management's report was not subject to attestation by our independent registered public accounting firm pursuant to rules of the SEC that permit us to provide only management's report in this annual report.
Changes in Internal Control Over Financial Reporting
There were no changes in our internal control over financial reporting (as such term is defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) during the fourth quarter of 2024 that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

---

ITEM 9B. OTHER INFORMATION
ITEM 9B. OTHER INFORMATION
During the three months ended December 31, 2024, none of our directors or officers (as defined in Rule 16a-1 under the Exchange Act) adopted or terminated any contract, instruction, or written plan for the purchase or sale of our securities that was intended to satisfy the affirmative defense conditions of Rule 10b5-1(c) or any "non-Rule 10b5-1 trading arrangement" (as defined in Item 408 of Regulation S-K).

---

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE OF THE REGISTRANT
Omitted pursuant to General Instruction I(2)c.

---

ITEM 11. EXECUTIVE COMPENSATION
ITEM 11. EXECUTIVE COMPENSATION
Omitted pursuant to General Instruction I(2)c.

---

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
Omitted pursuant to General Instruction I(2)c.

---

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
Omitted pursuant to General Instruction I(2)c.

---

ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
The following is a summary of the fees for professional services provided to us by Deloitte & Touche LLP in 2024 and 2023:
Fees 2024 2023
Audit fees (1)
$ 1,094,217 $ 1,073,433
Tax fees (2)
35,795 46,017
All other fees (3)
673 673
Total fees $ 1,130,685 $ 1,120,123
(1) Audit fees. Consists of aggregate fees for the audits of the annual financial statements and reviews of the interim condensed financial statements included in quarterly reports. Audit fees also include services that are normally provided by Deloitte & Touche LLP in connection with statutory and regulatory filings or engagements, including comfort letters, consents, and other services related to SEC matters, and consultations arising during the course of the audits and reviews concerning financial accounting and reporting standards.
(2) Tax fees. Consists of fees for professional services rendered with respect to federal and state tax compliance and tax advice. This can include preparation of tax returns, claims for refunds, payment planning, and tax law interpretation.
(3) All other fees. Consists of fees for services provided to us by Deloitte & Touche LLP for products and services other than the services reported above. All Other Fees relate to utility training seminars and a subscription cost for the use of a Deloitte & Touche LLP accounting research tool.
No fees were paid to Deloitte & Touche LLP pursuant to the "de minimus" exception to the pre-approval policy permitted under the Exchange Act.
Policy on Audit Committee Pre-Approval of Audit and Permissible Non-Audit Services of Independent Registered Public Accounting Firm
The AOC, which is comprised solely of independent directors, is responsible for reviewing and approving, in advance, all audit, audit-related, tax, and other services of the independent auditor. The AOC has the sole authority to select, evaluate, and where appropriate, terminate and replace the independent auditor.
The AOC is committed to ensuring the independence of the auditor, both in appearance as well as in fact. In order to assure continuing auditor independence, the AOC periodically considers whether there should be a regular rotation of the independent external audit firm. In addition, the AOC is directly involved in the selection of the independent auditor's lead audit partner.
2024 Form 10-K 102
Wisconsin Public Service Corporation
Pre-Approval Process
Before engagement of the independent auditor for the next year's audit, the independent auditor will submit (i) a description of all services anticipated to be rendered during the following year, as well as an estimate of the fees for each of the services, for the AOC to approve, and (ii) written confirmation that the performance of any non-audit services is permissible and will not impact the firm's independence. Annual pre-approval will be deemed effective for a period of twelve months from the date of the pre-approval, unless the AOC specifically provides for a different period. A fee level will be established for all permissible, pre-approved non-audit services. Any additional audit service, audit related service, tax service and other service must also be pre-approved.
The AOC delegated pre-approval authority to the AOC's chair. The AOC chair is required to report any pre-approval decisions at the next AOC meeting. Under the pre-approval policy, the AOC may not delegate to management its responsibilities to pre-approve services performed by the independent auditor.
Prohibited Activities are services prohibited by the SEC or by the Public Company Accounting Oversight Board to be performed by our independent auditor. These services include:
•bookkeeping or other services related to the accounting records or financial statements of WEC Energy Group or its subsidiaries;
•financial information systems design and implementation;
•appraisal or valuation services, fairness opinions or contribution-in-kind reports;
•actuarial services;
•internal audit outsourcing services;
•management functions or human resources;
•broker-dealer, investment advisor or investment banking services;
•legal services and expert services unrelated to the audit;
•services provided for a contingent fee or commission; and
•services related to planning, marketing or opining in favor of the tax treatment of a confidential transaction or aggressive tax position transaction that was initially recommended, directly or indirectly, by the independent auditor.
In addition, the independent auditor may not provide any services, including personal financial counseling and tax services, to any officer or other employee of WEC Energy Group or its subsidiaries who serves in a financial reporting oversight role or to the chair of the AOC or to an immediate family member of these individuals, including spouses, spousal equivalents, and dependents.
2024 Form 10-K 103
Wisconsin Public Service Corporation
PART IV

---

ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
1. Financial Statements and Report of Independent Registered Public Accounting Firm Included in Part II of This Report
Description Page in 10-K
Report of Independent Registered Public Accounting Firm (PCAOB No. 34).
Income Statements for the three years ended December 31, 2024, 2023, and 2022.
Balance Sheets as of December 31, 2024 and 2023.
Statements of Cash Flows for the three years ended December 31, 2024, 2023, and 2022.
Statements of Equity for the three years ended December 31, 2024, 2023, and 2022.
Notes to Financial Statements.
2. Financial Statement Schedules Included in Part IV of This Report
Schedule II, Valuation and Qualifying Accounts, for the three years ended December 31, 2024, 2023, and 2022.
Other schedules are omitted because of the absence of conditions under which they are required or because the required information is given in the financial statements or notes thereto.
3. Exhibits and Exhibit Index
The following exhibits are filed or furnished with or incorporated by reference in the report with respect to Wisconsin Public Service Corporation (File No. 1-3016). An asterisk (*) indicates that the exhibit has previously been filed with the SEC and is incorporated herein by reference.
Number Exhibit
3 Articles of Incorporation and By-laws
3.1*
Restated Articles of Incorporation of Wisconsin Public Service Corporation ("WPS''), as effective May 26, 1972, and amended through May 31, 1988 and Articles of Amendment to Restated Articles of Incorporation of WPS dated June 9, 1993. (Exhibit 4.1 to Registration Statement on Form S-3, Reg. No. 333-182491, filed 07/02/12.)
3.2*
By-Laws of WPS, as amended through June 29, 2015, Inclusive. (Exhibit 3.2 to Form 10-K for the year ended 12/31/15.)
4 Instruments defining the rights of security holders, including indentures
4.1*
Indenture, dated as of December 1, 1998, by and between WPS and U.S. Bank National Association (successor to Firstar Bank Milwaukee, N.A., National Association). (Exhibit 4A to Form 8-K filed 12/18/98.)
4.2*
First Supplemental Indenture, dated as of December 1, 1998, by and between WPS and Firstar Bank Milwaukee, N.A., National Association. (Exhibit 4C to Form 8-K filed 12/18/98.)
4.3*
Fifth Supplemental Indenture, dated as of December 1, 2006, by and between WPS and U.S. Bank National Association. (Exhibit 4.1 to Form 8-K filed 11/30/06.)
4.4*
Ninth Supplemental Indenture, dated as of December 1, 2012, by and between WPS and U.S. Bank National Association. (Exhibit 4.1 to Form 8-K filed 11/29/12.)
2024 Form 10-K 104
Wisconsin Public Service Corporation
Number Exhibit
4.5*
Tenth Supplemental Indenture, dated as of November 1, 2013, by and between WPS and U.S. Bank National Association. (Exhibit 4.1 to Form 8-K filed 11/18/13.)
4.6*
Thirteenth Supplemental Indenture, dated as of August 14, 2019, by and between WPS and U.S. Bank National Association. (Exhibit 4.1 to Form 8-K filed 08/14/19.)
4.7*
Fourteenth Supplemental Indenture, dated as of November 18, 2021, by and between WPS and U.S. Bank National Association. (Exhibit 4.1 to Form 8-K filed 11/18/21.)
4.8*
Fifteenth Supplemental Indenture, dated as of November 10, 2022, by and between WPS and U.S. Bank Trust Company, National Association (formerly U.S. Bank National Association). (Exhibit 4.1 to Form 8-K filed 11/10/22.)
4.9*
Sixteenth Supplemental Indenture, dated as of December 6, 2024, by and between WPS and U.S. Bank Trust Company, National Association (successor to Firstar Bank, Milwaukee, N.A., National Association (Exhibit 4.1 to Form 8-K filed December 6, 2024).
The forgoing list of exhibits does not include certain unregistered long-term debt instruments of the Registrant where the total amount of securities authorized to be issued under the instrument does not exceed 10% of the total assets of the Registrant. We agree pursuant to Item 601(b)(4) of Regulation S-K to furnish to the Securities and Exchange Commission, upon request, a copy of all such agreement and instruments.
10 Material Contracts
10.1* #
Joint Plant Agreement by and between WPS and Dairyland Power Cooperative, dated as of November 23, 2004. (Exhibit 10.19 to Integrys Energy Group's and WPS's Form 10-K for the year ended 12/31/04.)
Note: Certain compensatory plans, contracts or arrangements in which directors or executive officers of WPS participate are not filed as WPS exhibits in reliance on the exclusion in Item 601(b)(10)(iii)(C)(6) of Regulation S-K. WPS is a wholly-owned subsidiary of WEC Energy Group, Inc., Commission File No. 001-09057, and such compensatory plans, contracts or arrangements are filed as exhibits to WEC Energy Group’s periodic reports under the Securities Exchange Act of 1934.
19 Insider Trading Policies and Procedures
19.1
Corporate Securities Trading Policy
23 Consents of Experts and Counsel
23.1
Deloitte & Touche LLP - Milwaukee, WI, Consent of Independent Registered Public Accounting Firm for WPS.
31 Rule 13a-14(a) / 15d-14(a) Certifications
31.1
Certification Pursuant to Rule 13a-14(a) or 15d-14(a), as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2
Certification Pursuant to Rule 13a-14(a) or 15d-14(a), as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32 Section 1350 Certifications
32.1
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
2024 Form 10-K 105
Wisconsin Public Service Corporation
Number Exhibit
101 Interactive Data File
101.INS Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
101.SCH Inline XBRL Taxonomy Extension Schema
101.CAL Inline XBRL Taxonomy Extension Calculation Linkbase
101.DEF Inline XBRL Taxonomy Extension Definition Linkbase
101.LAB Inline XBRL Taxonomy Extension Label Linkbase
101.PRE Inline XBRL Taxonomy Extension Presentation Linkbase
104 Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)
# Portions of this exhibit have been redacted and are subject to a confidential treatment request filed with the Secretary of the SEC pursuant to Rule 24b-2 under the Securities and Exchange Act of 1934, as amended. The redacted material was filed separately with the SEC.