10-Q: WEC Energy Group Q3 Earnings Rise, Boosted by Rate Orders

WEC Energy Group reported a significant increase in Q3 2025 net income, driven by favorable Wisconsin rate orders and higher retail sales volumes, despite increased operating expenses.

Summary

• Net income attributed to common shareholders increased by $31.2 million to $271.3 million in Q3 2025, compared to $240.1 million in Q3 2024.
• Diluted Earnings Per Share (EPS) rose to $0.83 in Q3 2025 from $0.76 in Q3 2024.
• For the nine months ended September 30, 2025, net income attributed to common shareholders increased by $167.2 million to $1,240.9 million, up from $1,073.7 million in the prior year.
• Nine-month diluted EPS increased to $3.85 in 2025 from $3.40 in 2024.
• The Wisconsin segment's earnings increased by $43.5 million in Q3 2025, primarily due to favorable rate orders effective January 1, 2025, and higher retail sales volumes.
• The Illinois segment's net loss decreased by $18.1 million in Q3 2025, benefiting from the absence of a $25.3 million pre-tax charge recorded in Q3 2024 related to an ICC disallowance.
• Capital expenditures for the nine months ended September 30, 2025, totaled $3,095.1 million, an increase of $1,160.4 million from $1,934.7 million in the same period of 2024.
• The company acquired a 90% ownership interest in Hardin III, a 250 MW solar generating facility, for $406.1 million in February 2025.
• WEC Energy Group reconsidered its near-term CO2 emission reduction goals due to tightened energy supply requirements in the Midwest power market, but its long-term goal of net carbon neutral electric generation by 2050 remains intact.
• The company plans to invest approximately $11.6 billion from 2026 to 2030 in regulated renewable energy in Wisconsin, including 3,700 MW of solar, 1,780 MW of battery storage, and 555 MW of wind.
• PGL was directed by the ICC to focus on retiring all cast and ductile iron pipe under 36 inches by January 1, 2035, through its Pipe Retirement Program (PRP).

Sentiment

Score: 7

Explanation: The company reported strong earnings growth and increased EPS, driven by favorable rate orders and strategic investments in renewables. However, there are notable increases in operating expenses, significant capital outlays, and ongoing regulatory uncertainties, particularly in Illinois, which could impact future profitability and investment recovery. The reconsideration of near-term CO2 goals also adds a layer of complexity.

Positives

• Net income attributed to common shareholders increased by $31.2 million in Q3 2025 and $167.2 million for the nine months ended September 30, 2025, compared to the prior year periods.
• Diluted EPS increased by $0.07 in Q3 2025 and $0.45 for the nine months ended September 30, 2025.
• Wisconsin segment earnings rose by $43.5 million in Q3 2025, driven by favorable rate orders effective January 1, 2025, and higher retail sales volumes.
• Illinois segment net loss decreased by $18.1 million in Q3 2025, benefiting from the absence of a $25.3 million pre-tax charge recorded in Q3 2024 related to an ICC disallowance.
• Electric transmission segment net income increased by $5.6 million in Q3 2025 and $16.6 million for the nine months, due to continued capital investment by ATC and a gain from an investment sale.
• Non-utility energy infrastructure segment operating income increased by $15.2 million in Q3 2025 from new investments in several renewable generation facilities.
• Net cash provided by operating activities increased by $324.8 million for the nine months ended September 30, 2025, due to higher overall collections from customers and increased distributions from ATC.
• Successfully issued $900.0 million of 2028 Convertible Senior Notes in June 2025.
• The Board of Directors increased the quarterly dividend by $0.0575 per share (6.9%) effective with the March 2025 dividend payment.
• Moody's changed the rating outlook for PGL to stable from negative in March 2025.
• Continued progress on renewable energy projects, with Paris Solar-Battery Park (Solar) and Darien Solar Park (Solar) achieving commercial operation.
• Entered into agreements in October 2024, April 2025, and September 2025 to sell the majority of 2025 and 2026 Production Tax Credits (PTCs) and Investment Tax Credits (ITCs) to third parties, and an agreement in May 2025 to sell the majority of remaining unsold 2024 PTCs.

Negatives

• Other states segment net loss increased by $5.2 million in Q3 2025 due to higher property and revenue taxes and increased interest expense.
• Corporate and other segment net loss increased by $33.7 million in Q3 2025 and $50.9 million for the nine months, driven by higher interim income tax expense, increased interest expense, and net losses from equity method investments in technology and energy-focused funds.
• Non-utility energy infrastructure segment operating income decreased by $13.2 million for the nine months, primarily due to a $16.9 million impairment loss from storm damage at solar facilities and lower performance payments.
• Increased operating expenses in the Wisconsin segment, including depreciation and amortization, power plant costs, and property and revenue taxes.
• Net cash used in investing activities increased significantly by $1,517.3 million for the nine months, primarily due to higher capital expenditures and acquisitions.
• PGL and NSG face pending QIP reconciliations from 2017 through 2023, with ICC staff recommending significant disallowances in the 2017 proceeding, potentially impacting approximately $2.9 billion in aggregate capital costs.
• PGL was ordered by the ICC to pause spending on its natural gas delivery system upgrades, and future natural gas investment opportunities in Illinois could be negatively impacted by the ongoing 'Future of Gas' proceeding.
• Storm damage at Samson I and Delilah I solar facilities resulted in an $8.8 million impairment loss in Q2 2025, which was increased to $12.0 million in Q3 2025.
• Reconsideration of near-term CO2 emission reduction goals due to tightened energy supply requirements, indicating a potential slowdown in immediate decarbonization efforts.
• Increased interest expense across segments due to long-term debt issuances.

Risks

• Factors affecting utility and non-utility energy infrastructure operations such as catastrophic weather-related damage, environmental incidents, unplanned facility outages and repairs and maintenance, electric grid reliability, and electric transmission or natural gas pipeline system constraints.
• Factors affecting the demand for electricity and natural gas, including political or regulatory developments, varying, adverse, or unusually severe weather conditions, changes in economic conditions, customer growth and declines, commodity prices, energy conservation efforts, and continued adoption of distributed generation.
• The timing, resolution, and impact of rate cases and negotiations, including recovery of deferred and current costs and the ability to earn a reasonable return on investment, and other regulatory decisions impacting regulated operations.
• The impact of federal, state, and local legislative and/or regulatory changes, including changes in rate-setting policies or procedures, deregulation and restructuring of the electric and/or natural gas utility industries, transmission or distribution system operation, approval process for new construction, reliability standards, pipeline integrity and safety standards, allocation of energy assistance, energy efficiency mandates, electrification initiatives, and tax laws.
• Federal, state, and local legislative and regulatory changes relating to the environment, including climate change and other environmental regulations impacting generation facilities and renewable energy standards, the enforcement of these laws and regulations, changes in and uncertainty regarding the interpretation of regulations or permit conditions by regulatory agencies, and the recovery of associated remediation and compliance costs.
• The ability to obtain and retain customers, including wholesale customers, due to increased competition.
• The timely completion of capital projects within budgets and the ability to recover the related costs through rates.
• The impact of changing expectations and demands of customers, regulators, investors, and other stakeholders, including focus on environmental, social, and governance concerns.
• The risk of delays and shortages, and increased costs of equipment, materials, or other resources due to changes to U.S. trade policy (tariffs, port fees), foreign governments' trade policies, supply chain disruptions (rail congestion), inflation, and other factors.
• Risks related to providing service to data center and other large-scale customers, including project termination, cancellation or delay, failure to receive regulatory approvals or permits, delays in recovery of contractual reimbursement, ability to fully recover investment, and lower than anticipated need for electricity.
• The impact of public health crises, including epidemics and pandemics, on business functions, financial condition, liquidity, and results of operations.
• Risks inherent in electric generation and distribution and natural gas transportation, distribution, and storage activities, including leaks, accidental explosions, mechanical problems, fires, discharges or releases of toxic or hazardous substances or gases, and risks related to obtaining adequate insurance.
• Factors affecting the implementation of CO2 emission reduction goals, including regulatory decisions, cost of materials/labor, technology advances, demand increases, feasibility of competing projects, and ability to execute capital plan.
• The financial and operational feasibility of taking more aggressive action to further reduce GHG emissions.
• The risks associated with inflation and changing commodity prices, including natural gas and electricity.
• The availability and cost of sources of natural gas and other fossil fuels, purchased power, materials for environmental controls, or water supply due to high demand, shortages, transportation problems, nonperformance by suppliers, or other developments.
• Any impacts on the global economy, including from sanctions, and impacts on supply chains and fuel prices from ongoing, expanding, or escalating regional or international conflicts (Ukraine, Israel, Middle East).
• Changes in credit ratings, interest rates, and ability to access capital markets.
• Costs and effects of litigation, administrative proceedings, investigations, settlements, claims, and inquiries.
• The direct or indirect effect on business from terrorist or other physical attacks and cybersecurity intrusions, including failure to maintain security of personally identifiable information.
• Restrictions imposed by financing arrangements and regulatory requirements on subsidiaries' ability to transfer funds to the parent.
• The risk of financial loss, including increases in bad debt expense, associated with the inability of customers, counterparties, and affiliates to meet obligations.
• Changes in the creditworthiness of counterparties.
• The financial performance of ATC and its corresponding contribution to earnings.
• The investment performance of employee benefit plan assets and unanticipated changes in actuarial assumptions.
• Factors affecting the employee workforce, including loss of key personnel, internal restructuring, work stoppages, and collective bargaining agreements.
• Advances in technology and related legislation/regulation that result in competitive disadvantages and potential impairment of existing assets.
• Risks involved in developing and implementing AI, including data privacy, legal liability, governmental/regulatory scrutiny, and ability to meet expectations.
• Risks related to non-utility renewable energy facilities, including unfavorable weather, changes in counterparty financial performance/creditworthiness, changes in demand, pricing differentials, ability to replace expiring PPAs, property rights, interconnection/grid reliability, component performance/quality, and exposure to power market rules.
• The risk associated with the values of goodwill and other long-lived assets, including intangible assets, and equity method investments and their possible impairment.
• Potential business strategies to acquire and dispose of assets or businesses, which cannot be assured to be completed timely or within budgets, and legislative or regulatory restrictions or caps on non-utility acquisitions, investments or projects.
• The timing and outcome of any audits, disputes, and other proceedings related to taxes.
• The effect of accounting pronouncements issued periodically by standard-setting bodies.
• Uncertainty regarding the long-term impact of the Uyghur Forced Labor Prevention Act (UFLPA) on solar panel supply and project timing/cost.
• Increased costs and delays in solar projects due to Department of Commerce (DOC) duties on imports from Southeast Asian countries.
• Potential negative impact on future natural gas investment opportunities in Illinois from the 'Future of Gas' proceeding.
• Material adverse impact on PGL's future natural gas operations if the Chicago Clean and Affordable Buildings Ordinance (CABO) is passed.
• Potential reduction of future after-tax equity earnings from ATC by approximately $8 million annually if FERC limits the 50 basis point Return on Equity (ROE) incentive for transmission organization membership.
• Uncertainty of recovery for all costs incurred under the Uncollectible Expense Adjustment (UEA) rider during open reconciliation years (2019-2024), with potential material disallowances.
• Uncertainty of recovery for all capital costs and previously recognized returns under PGL's Qualifying Infrastructure Plant (QIP) rider during open reconciliation years (2017-2023), totaling approximately $2.9 billion, with potential material adverse impact.
• Risk of significant losses or delayed recovery of costs related to large-scale customer projects (e.g., data centers) if projects are canceled, regulatory approvals are not received, or customers reduce anticipated load.
• Concentration of business with a small number of customers in emerging technologies (AI, machine learning) presents risks of reduced demand, customer downturn, early termination, or non-renewal of service agreements.

Future Outlook

WEC Energy Group maintains its long-term goal of achieving net carbon neutral electric generation by 2050, despite reconsidering near-term CO2 emission reduction goals due to Midwest power market supply requirements. The company plans aggressive capital investments of approximately $11.6 billion from 2026 to 2030 in regulated renewable energy (solar, battery storage, wind) and clean natural gas-fired generation in Wisconsin, alongside $4.7 billion for electric distribution reliability. Coal is expected to be a backup fuel by the end of 2030 and eliminated as an energy source by the end of 2032. The 2025 annual effective tax rate is projected to be between 7.5% and 8.5%. The company anticipates maintaining adequate liquidity and compliance with debt covenants. Key regulatory decisions are expected, including a PSCW decision on VLC and Bespoke Resources Tariffs in Q2 2026 and the initiation of an Illinois general rate case in early 2026 for PGL's infrastructure spending. UMERC expects to recover Renegade project costs via a renewable energy surcharge starting January 2026. The company is actively monitoring various EPA deregulatory actions and ongoing litigation that could impact environmental compliance and project timelines.

Management Comments

• Our goal is to continue to build and sustain long-term value for our shareholders and customers by focusing on the fundamentals of our business: environmental stewardship; reliability; operating efficiency; financial discipline; exceptional customer care; and safety.
• Our capital plan provides a roadmap for us to achieve this goal. It is an aggressive plan to cut emissions, maintain superior reliability, deliver significant savings for customers, and grow our investment in the future of energy.
• In the third quarter of 2025, we made a decision to reconsider our near-term CO2 emission reduction goals due to a combination of factors, including tightened energy supply requirements in the Midwest power market and the need to serve our customers with safe, reliable, and affordable energy. However, our long-term goal to achieve net carbon neutral electric generation by 2050 remains intact.
• We expect to use coal only as a backup fuel by the end of 2030 and to be in a position to eliminate coal as an energy source by the end of 2032.
• In light of our progress, significant uncertainty surrounding the market for Renewable Thermal Credits (RTCs), and our desire to focus on long-term Greenhouse Gas (GHG) emissions-reduction across the enterprise, in the third quarter of 2025, we made a decision to reassess our previous, standalone goal related to methane emissions from natural gas distribution.
• We expect to initiate a general rate case proceeding in early 2026, which we anticipate will provide further regulatory clarity before we significantly increase our spend associated with our Pipe Retirement Program (PRP).
• 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.
• We believe that these agreements [off-balance sheet arrangements] 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.

Industry Context

WEC Energy Group's Q3 2025 performance and strategic direction reflect broader trends in the U.S. utility sector, particularly the ongoing energy transition. The company's substantial capital plan for regulated renewables (solar, wind, battery storage) and efficient natural gas generation aligns with the industry's shift towards decarbonization and grid modernization. The focus on serving large-scale data centers highlights a growing demand segment for electricity, presenting both opportunities and risks for utilities. Regulatory challenges, such as the 'Future of Gas' proceeding in Illinois and various EPA deregulatory actions, are common across the utility industry as it navigates environmental compliance and policy shifts. The reconsideration of near-term CO2 goals due to 'tightened energy supply requirements in the Midwest power market' indicates regional grid reliability challenges that many utilities face during the energy transition. Supply chain disruptions, inflation, and U.S. trade policy changes (tariffs on solar panels, UFLPA) are industry-wide concerns impacting project costs and timelines for renewable energy development.

Legal Proceedings

• PGL and NSG filed a petition with the Illinois Appellate Court for review of the ICC's November 16, 2023, and May 30, 2024, orders regarding rate increases and capital cost disallowances.
• PGL and NSG's petition to the Illinois Supreme Court seeking review and reversal of the May 2023 order (2018 UEA rider reconciliation) was denied in March 2025.
• PGL's QIP reconciliations from 2017 through 2023 are still pending, with ICC staff recommending significant disallowances in the 2017 proceeding.
• Appeals related to the October 2024 FERC Order on ATC's ROE are still pending before the D.C. Circuit Court of Appeals.
• The Wisconsin Department of Justice filed a petition in February 2025 for review of the reclassification to 'serious' for ozone nonattainment, and the U.S. Court of Appeals for the Seventh Circuit granted a stay.
• Numerous parties have challenged the Greenhouse Gas Power Plant Rule through litigation pending in the D.C. Circuit Court of Appeals.
• Numerous parties have challenged the 2024 Supplemental ELG Rule through litigation in SWEPCO v. U.S. EPA pending in the United States Court of Appeals for the Eighth Circuit.
• The CCR rule is being challenged through litigation pending in the D.C. Circuit Court of Appeals.
• The Consent Decree related to the jointly owned Columbia Energy Center and Edgewater Generating Station plants was terminated on August 6, 2025.

Related Party Transactions

• WEC Energy Group owns approximately 60% of ATC and approximately 75% of ATC Holdco, accounting for them as equity method investments.
• WEC Energy Group pays ATC for network transmission and other related services.
• WEC Energy Group provides operational, maintenance, and project management work for ATC, which is reimbursed.
• WEC Energy Group initially funds construction of transmission infrastructure upgrades for new generation projects, and ATC reimburses these costs when new generation is in service.
• Bluewater has long-term service agreements for natural gas storage services with WE, WPS, and WG, with intercompany amounts eliminated at the consolidated level.
• We Power owns and leases generating facilities to WE, with lease payments billed from We Power to WE and recovered in WE's rates.

Stakeholder Impact

• Shareholders: Experienced increased net income and EPS, and an increased quarterly dividend, indicating positive financial returns. However, they face risks from potential regulatory disallowances and market volatility.
• Customers: Are subject to higher rates due to Wisconsin rate orders but may receive refunds from Illinois regulatory mechanisms (UEA rider, QIP). They benefit from the company's focus on reliable and affordable energy, and expansion of EV charging and RNG programs. However, there is potential for increased costs from new large-scale customer tariffs (VLC/Bespoke Resources) if not managed carefully.
• Employees: Benefit from stock-based compensation awards and the company's strong focus on safety through its 'Target Zero' mission. There is potential for internal restructuring.
• Suppliers/Contractors: The significant capital plan creates substantial business opportunities. However, they face risks of delays, shortages, and increased costs due to supply chain disruptions, inflation, and trade policies.
• Regulators: Are actively engaged with the company on rate cases, environmental compliance, infrastructure investments, and new tariffs, reflecting their oversight role.
• Communities: Benefit from environmental stewardship through emission reduction goals, though the reconsideration of near-term CO2 goals might impact local environmental efforts. Infrastructure upgrades aim to improve reliability for the communities served.

Next Steps

• Monitor and evaluate potential risks and benefits from the EPA's 31 deregulatory actions.
• Monitor the status of the EPA's proposal to rescind the 2009 endangerment finding for CO2 and other GHGs.
• Monitor the D.C. Circuit Court of Appeals case regarding the Good Neighbor Rule.
• Monitor the EPA's proposed rule to repeal the 2024 Final Action on MATS.
• Monitor the EPA's restarting of its ozone standard evaluation (anticipated 3-5 years to complete).
• The Wisconsin Department of Natural Resources (WDNR) will need to draft and submit a State Implementation Plan (SIP) for EPA's approval regarding the new PM2.5 standard.
• Monitor the D.C. Circuit Court of Appeals litigation challenging the Greenhouse Gas Power Plant Rule.
• Monitor the EPA's new rulemaking phases focusing on CO2, NOx, and formaldehyde emissions from CTs.
• Monitor the EPA's proposed rule and companion direct final rule to modify certain 2024 ELG Rule provisions.
• Monitor the SWEPCO v. U.S. EPA litigation challenging the 2024 Supplemental ELG Rule.
• Monitor the D.C. Circuit Court of Appeals litigation challenging the CCR rule.
• Monitor the 'Future of Gas' proceeding in Illinois (expected completion in 2026).
• Monitor the Chicago city council's decision on the CABO.
• Monitor new Antidumping (AD)/Countervailing Duty (CVD) investigations on solar imports from Laos, Indonesia, and India.
• Monitor the disbursement of funds under the Infrastructure Investment and Jobs Act and Inflation Reduction Act.
• PGL will retire cast and ductile iron pipe through its Pipe Retirement Program (PRP).
• WEC Energy Group expects to initiate a general rate case proceeding in Illinois in early 2026.
• UMERC expects to be authorized to begin recovering the annual revenue requirement of Renegade through a renewable energy surcharge in January 2026.
• A PSCW decision on the VLC Tariff and Bespoke Resources Tariff is expected in Q2 2026.
• WEC Energy Group plans to file a NOPP by December 31, 2025, to opt into the 'cessation of coal by December 31, 2034' subcategory for ERGS and Weston coal-fired facilities.
• WEC Energy Group plans to adopt new accounting pronouncements on income tax disclosures in the fiscal year ending December 31, 2025.
• WEC Energy Group plans to adopt new accounting pronouncements on income statement expense disaggregation in the fiscal year ending December 31, 2027.
• WEC Energy Group expects to make contributions and payments of $3.0 million related to pension plans and $1.2 million related to Other Postretirement Employee Benefits (OPEB) plans during the remainder of 2025.
• WEC Energy Group expects to provide total capital contributions to ATC of approximately $645 million from 2026 through 2028.
• WEC Energy Group expects to invest approximately $700 million in MISO Tranche 1 between 2026 and 2030.

Key Dates

Recommendation

WEC Energy Group demonstrates solid financial performance with increased earnings and EPS, supported by favorable rate orders and a robust capital plan focused on regulated renewables and infrastructure. The dividend increase signals confidence. However, significant regulatory uncertainties in Illinois, particularly the potential for material disallowances in QIP reconciliations and the 'Future of Gas' proceeding, pose considerable risks to future earnings and investment recovery. The reconsideration of near-term CO2 goals and the inherent risks associated with large-scale data center projects also introduce caution. While the long-term strategy for clean energy transition is positive, the near-term regulatory and operational headwinds warrant a 'Hold' recommendation until there is greater clarity on these challenges.

Keywords

WEC Energy Group, Utility, Electric, Natural Gas, Renewable Energy, Solar, Wind, Battery Storage, Capital Plan, Earnings, EPS, SEC Filing, 10-Q, Regulatory, FERC, PSCW, ICC, ESG, Climate Change, Data Centers, Infrastructure, Debt, Dividends, Illinois, Wisconsin, Michigan, Minnesota, ATC, Hardin III, Samson I, QIP, UEA, OBBBA, IRA, UFLPA, Tariffs