1 Energizing the Future Investor Update: November 2025

2 Cautionary Statement Regarding Forward-Looking Information Much of the information contained in this presentation is forward-looking information based upon management’s current expectations and projections that involve risks and uncertainties. Forward-looking information includes, among other things, information concerning earnings per share, rate case activity, earnings per share growth, cash flow, sources of revenue, dividend growth and dividend payout ratios, sales volumes, capital plans, credit ratings, credit metrics, debt-financings, construction costs, investment opportunities, corporate initiatives, rate base, and environmental matters (including emission reductions). Readers are cautioned not to place undue reliance on this forward-looking information. Forward-looking information is not a guarantee of future performance and actual results may differ materially from those set forth in the forward-looking information. Factors that could cause actual results to differ materially from those contemplated in any forward-looking statements include, but are not limited to: general economic conditions, including business and competitive conditions in the company’s service territories; timing, resolution and impact of rate cases and other regulatory decisions, including rider reconciliations; the company’s ability to continue to successfully integrate the operations of its subsidiaries; availability of the company’s generating facilities and/or distribution systems; unanticipated changes in fuel and purchased power costs; key personnel changes; unusual, varying or severe weather conditions; continued industry restructuring and consolidation; continued advances in, and adoption of, new technologies that produce power or reduce power consumption; energy and environmental conservation efforts; electrification initiatives, mandates and other efforts to reduce the use of natural gas; the company’s ability to successfully acquire and/or dispose of assets and projects and to execute on its capital plan, including projects related to providing services to data centers and other large-scale customers; terrorist, physical or cyber-security threats or attacks and data security breaches; construction risks; labor disruptions; equity and bond market fluctuations; changes in the company’s and its subsidiaries’ ability to access the capital markets; changes in tax legislation or our ability to use certain tax benefits and carryforwards; changes in and uncertainty around federal, state, and local legislation and regulation, including changes resulting from the current U.S. presidential administration, in rate-setting policies or procedures and environmental standards, in the enforcement of these laws and regulations and in the interpretation of regulations or permit conditions by regulatory agencies; supply chain disruptions; inflation; political or geopolitical developments, including impacts on the global economy, supply chain and fuel prices, generally, including as a result of changes to U.S. and foreign government trade policies, or from ongoing, escalating, or expanding regional or international conflicts; the impact from any health crises, including epidemics and pandemics; current and future litigation and regulatory investigations, proceedings or inquiries; the ability of the Company to successfully and/or timely adopt new technologies, including artificial intelligence; changes in accounting standards; the financial performance of the American Transmission Company as well as projects in which the company’s energy infrastructure business invests; the ability of the company to obtain additional generating capacity at competitive prices; goodwill and its possible impairment; and other factors described under the heading “Factors Affecting Results, Liquidity and Capital Resources” in Management’s Discussion and Analysis of Financial Condition and Results of Operations and under the headings “Cautionary Statement Regarding Forward-Looking Information” and “Risk Factors” contained in WEC Energy Group’s Form 10-K for the year ended December 31, 2024, and in subsequent reports filed with the Securities and Exchange Commission. Except as may be required by law, WEC Energy Group expressly disclaims any obligation to publicly update or revise any forward-looking information.

3 A Premier Energy Company in America’s Heartland * As of Oct. 31, 2025 $36.3 billion market cap* 4.7 million retail customers $49.8 billion of assets 60% ownership of American Transmission Company Ranked first overall in the 2025 E Source Large Business Customer Satisfaction Study

4 $1 $2 $3 $4 $5 $6 '15 '16 '17 '18 '19 '20 '21 '22 '23 '24 '25E * Estimated based on 2025 guidance midpoint of $5.22 per share. ** See Appendix for reconciliation of adjusted amounts to GAAP amounts. $5.17-$5.27 $3.57** $1 $2 $3 $4 '15* '16 '17 '18 '19 '20 '21 '22 '23 '24 '25E * Annualized based on 4th quarter 2015 dividend of 45.75 cents per share. ** Annualized based on 1st quarter 2025 dividend of 89.25 cents per share. Exceeded or achieved EPS guidance for multiple decades History of Consistent, Strong Earnings and Dividend Growth ~6.7% CAGR* Annualized Dividends Per Share ~6.9% CAGR Earnings Per Share GAAP Adjusted** 2025 Guidance

5 21 consecutive years of exceeding or meeting top end of earnings guidance* Consistent Performance Over Time * On an adjusted basis

6 2025E 2026 2027 2028 2029 2030 $5.17 - $5.27 Robust Long-Term EPS Growth Outlook 1. Growth rate based on 2025 guidance midpoint of $5.22 per share. 2025 Guidance

7 Strong Dividend Growth Continues  In January, dividend was raised by 6.9% to a new annual rate of $3.57 per share*  22nd consecutive year of rewarding shareholders with higher dividends  Top-decile dividend growth in industry**  Included in S&P's High Yield Dividend Aristocrats Index  Expect to grow dividend at a rate of 6.5-7%  Targeting payout ratio of 65-70% of earnings * Annualized based on the first quarter 2025 dividend of 89.25 cents per share. ** Reflects current and expected dividends declared in 2025.

8 Powering Industry Leaders in Our Region

9 Longer-Term Sales and Load Growth Remain Strong Wisconsin Segment Year-Over-Year 2028-2030 Electric 6.0%-7.0% Gas 0.7%-1.0% Sales Growth Forecast (weather-normalized) 2026-2030 expecting to add 3.4 GW (~40%) of electric demand

10 2.1 GW of Demand Forecasted through 2030 Robust demand along I-94 Milwaukee to Chicago corridor: Microsoft Data Center  Announced investment of $7+ billion  2,300 construction jobs  2,000 permanent jobs over time  More than 2,000 acres purchased to date  Expansion investment in progress  Operations expected to commence in 2026 Strong Regional Growth ‘Mount Pleasant AI data center will be among the world’s most advanced’ –Brad Smith, President of Microsoft BizTimes Milwaukee © Microsoft

11 Strong Regional Growth 1.3 GW of Demand Forecasted through 2030 Vantage Data Centers plans to develop a large campus that will be part of OpenAI and Oracle’s partnership for the Stargate expansion:  Four data center buildings planned on 670 acres with expected investment of $15+ billion in Port Washington  4,000+ construction jobs  1,000+ permanent jobs  Site potential up to 3.5 GW over time  Approximately 1,900 acres © Vantage Data Centers Port Washington data center rendering

12 Wisconsin Very Large Customer (VLC) Tariff Meets the unique needs of very large customers while protecting other customers and shareholders  Applies to customers with 500 MW or more of forecasted new load  Customer subscribes to a portion of one or more dedicated new generation resources  Terms:  Wind and solar: 20 years  Depreciable life for natural gas and battery storage assets  Fixed for entire term: Return on Equity range of 10.48% to 10.98% and Equity Ratio of 57%, as agreed upon with customers  Revenues and costs recovered through tariff will be excluded from future rate case proceedings and earnings sharing mechanisms  Early termination: Customer pays for remaining net book value, to the extent it cannot be repurposed  Filed with the PSCW on March 31, 2025; all terms subject to PSCW approval  PSCW order required by May 1, 2026, for customers to take service on June 1, 2026

13 2026-2030 Capital Plan Capital Plan — Key Drivers Identified $8.5 billion of additional investments compared to previous five-year plan:  Generation  Natural gas generation — $3.4 billion increase  Regulated renewables — $2.5 billion increase  Transmission — $900 million increase  Electric distribution — $200 million increase  Pipe Retirement Program (PRP) — $1.5 billion increase  WEC Infrastructure — $400 million decrease

14 $13.2 $19.3 $1.4 $1.3 $4.5 $4.7 $5.3 $7.1 $3.2 $4.1 $0.4 $28.0 $36.5 2025-2029 2026-2030 WEC Infrastructure (WECI) Electric Transmission (ATC)* Gas Distribution** Electric Distribution WI LNG Capacity Electric Generation N e w p la n F o rm e r p la n *ATC is accounted for using the equity method; this represents WEC Energy Group’s portion of the investment. ** Includes all gas utilities and Bluewater. $ In billions Increasing Five-Year Capital Plan by $8.5 Billion 2026-2030 Capital Plan Supports 7.0% to 8.0% Long-Term EPS Growth

15 $36.5 Billion Projected Capital Spend From 2026-2030 Capital Plan Drives EPS Growth 2,286 2,581 4,311 4,412 3,983 3,948 155 178 82 112 326 623 966 972 946 973 805 1,025 949 1,287 1,611 1,469 1,336 1,378 513 657 802 886 896 901 406 $5,275 $5,675 $7,752 $7,852 $7,346 $7,875 - 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 2025 2026 2027 2028 2029 2030 WEC Infrastructure (WECI) Electric Transmission (ATC)* Gas Distribution** Electric Distribution WI LNG Capacity Electric Generation Depreciation at utilities expected to average $1.6 billion annually, and $190 million at ATC, over 2026-2030 period *ATC is accounted for using the equity method; this represents WEC Energy Group’s portion of the investment. ** Includes all gas utilities and Bluewater.

16 Diverse Portfolio of Businesses 63% 16% 4% 7% 10% WI IL MI/MN WECI ATC* By Jurisdiction By Business Based on average asset base. *ATC is accounted for using the equity method; this represents WEC Energy Group’s portion of the asset base. 2030E Asset base $58.5 billion2024A Asset base $30.8 billion 11.3% CAGR 57%24% 5% 4% 10% 49% 32% 2% 7% 10% 59% non-VLC/bespoke 14% VLC/bespoke 10% 3% 4% 10% 73% Total WI Electric generation and distribution Natural gas distribution LNG (distribution and generation) WECI Electric transmission*

17 Solar Total 3,700 MW $7.6 billion Battery Storage Total 1,780 MW $2.2 billion Wind Total 555 MW $1.8 billion Grand Total 6,035 MW $11.6 billion Investing $11.6 Billion in Regulated Renewables 2026-2030 Capital Plan Dollars exclude capital spend outside of 2026-2030.

18 2026-2030 Capital Plan Investing $7.4B in Our Thermal Generation Fleet and LNG Capacity Proposed Oak Creek Combustion Turbine and LNG Storage Facility Combustion Turbines 3,300 MW $5.2 billion RICE Generation 180 MW $240 million CCGT Summer Upgrades 150 MW $280 million Coal to Gas Conversions and Fuel Oil Backup $370 million Dollars exclude capital spend outside of 2026-2030. Investing $6.1B in our thermal generation fleet Modern, efficient natural gas generation serves as a critical resource in our energy transformation. Investing $1.3B in LNG Storage Facilities LNG provides a solution to ensure gas supply for power generation and to meet peak customer demand for heating. LNG Storage Facilities 6 Bcf $1.3 billion

19 $1,095 $1,337 $1,477 $1,493 $1,502 $657 $802 $886 $896 $901 2026 2027 2028 2029 2030 ATC WEC portion 60% Capital Drivers*:  Economic Growth  $1.4 billion  LRTP  Tranche 1  $700 million  Tranche 2  $400 million  $800 million additional investment expected 2031 and beyond (2024 dollars) WEC portion of ATC investment expected from 2026-2030: $4.1 billion Future Transmission Investment Projected Capital Expenditures (millions) * All amounts represent WEC’s 60% portion.

20 Pipe Retirement Program (PRP)  Plan to retire over 1,000 miles of older, cast and ductile iron pipe (less than 36 inches in diameter)  Annual investment for pipe replacement expected to ramp up to $500 million in 2028  ICC ordered program to be complete by January 1, 2035 Illinois

21 Projected Cash Flows and Financing Plan ($ in billions) Cash from Operations $20.5 - $21.5 Common Equity $4.8 - $5.2 Dividends $7.6 - $7.8 Capital Plan $32.3 Cash Uses Cash Sources Incremental Debt 2 $13.7 - $14.3 1. Excludes ATC’s capital. ATC is accounted for using the equity method. 2. Includes $5.0B - $6.0B of junior subordinated notes or other securities with equity content. 2026-2030 1

22 Credit Quality — Maintaining a Healthy Balance Sheet Current Issuer Credit Ratings Entity S&P Rating Moody’s Rating WEC Energy Group A- Baa1 Wisconsin Electric A- A2 Wisconsin Gas A A3 Wisconsin Public Service A- A2 Peoples Gas A- A2 FFO/Debt Metrics 2026-2030 WEC Energy Group Target S&P FFO to Debt >15% Moody’s CFO Pre-WC/Debt >16%

23 Coal Generation  Since 2018, we have retired nearly 2,500 MW of fossil fuel generation  Retirements planned:  Oak Creek Units 7-8: 611 MW (targeting end of 2026)  Weston Unit 3: 328 MW (expected end of 2031)  Enhancing fuel flexibility (gas blending) at Oak Creek Power the Future units and Weston Unit 4*  Evaluating the future of Columbia Units 1 and 2  Exploring conversion of both units to natural gas  By end of 2030, we expect to use coal only as a backup fuel. We plan to eliminate coal as an energy source by end of 2032 *Filed for acquisition of an additional 165 MW of Weston 4 for an estimated investment of $150 million. Pending regulatory approval.

24 * We are reconsidering our near-term 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, aligned with global emissions pathways aimed at limiting warming to 1.5°C. Tracking Carbon Reduction -100 -80 -60 -40 -20 0 2005 2024 Achieved CO2 reductions (net mass) -56% Goal*: Net carbon neutral by end of 2050 Electric Generation

25 Key Takeaways for WEC Energy Group  Consistent, strong earnings growth  Top-decile dividend growth  Capital plan supported by economic growth  Drives premium long-term EPS growth of 7.0% to 8.0%  100% of capital allocated to regulated businesses  Poised to deliver among the best risk-adjusted returns in the industry

Appendix

27 Electric Transmission 60% ownership Energy Infrastructure Electric DistributionElectric Generation Natural Gas Distribution

28 Solar Projects Docket Anticipated Approval WEC Capacity (MW) WEC Investment ($M) Ownership Anticipated In-Service Koshkonong Solar Park 5-BS-258 Approved 270 621E WEPCO/ WPS 90%1 2026 High Noon Solar Park 5-BS-276 270 576E 2027 Ursa Solar Park 5-BS-280 Q4 2025 180 406E 2027 Saratoga Solar Park 135 314E 2028 Dawn Harvest Solar 5-BS-281 Q1 2026 135 303E 2028 Good Oak Solar Park 5-CE-159 88 194E 2028 Gristmill Solar Park 60 130E 2028 Sinissippi Solar Park 6630-BS-102 Q4 2026 100 277E WEPCO 100% 2028 Whitewater Solar Park 5-BS-287 180 411E WEPCO/WPS 100% 2028 Emerald Bluffs Solar Park 5-BS-288 203 510E WEPCO 90%1 2029 Dawn Break Solar Park 5-BS-289 162 377E 2029 Fox Solar Park 5-BS-290 90 238E 2028 Akron Solar Park 5-BS-291 180 461E 2029 Superior Solar Park 5-BS-292 135 354E 2028 Renegade Solar U-21081 Approved 100 226E UMERC 100% 2026 Regulated Renewable Generation and Storage Projects 1. Madison Gas and Electric owns/will own a minority interest at each site.

29 Battery Projects Docket Anticipated Approval WEC Capacity (MW) WEC Investment ($M) Ownership Anticipated In-Service Darien Battery Park 5-BS-255 Approved 68 140E WEPCO/WPS 90%1 2026 Koshkonong Battery Park 5-BS-258 149 309E 2027 High Noon Battery Park 5-BS-276 149 307E 2027 Saratoga Battery Park 5-BS-280 Q4 2025 45 92E 2028 Dawn Harvest Battery Park 5-BS-581 Q1 2026 50 106E WEPCO 100% 2028 Dawn Break Battery Park 5-BS-289 Q4 2026 162 320E WEPCO 90%1 2029 Regulated Renewable Generation and Storage Projects 1. Madison Gas and Electric owns/will own a minority interest at each site. Wind Projects Docket Anticipated Approval WEC Capacity (MW) WEC Investment ($M) Ownership Anticipated In-Service Badger Hollow Wind 5-BS-282 Q4 2025 100 320E WEPCO/WPS 90%1 2027 Whitetail Wind 60 200E 2027

30 Project Docket Anticipated Approval WEC Capacity (MW) WEC Investment ($M) Ownership Anticipated In-Service Oak Creek CTs 6630-CE-317 Approved 1,100 1,200E WEPCO 100% 2027/2028 Paris RICE generation 6630-CE-316 128 300E 2027 Oak Creek LNG 6630-CG-140 - 456E 2027 Rochester Lateral 6630-CG-139 - 200E 2027 ERGS Fuel Flexibility 5-CE-161 Q4 2026 - 132E WEPCO 83.34% 2028 PWGS Turbine Upgrade 6630-CE-318 100 227E WEPCO 100% 2028 Foundry Ridge CTs 6630-BS-103 270 550E 2028 Red Oak Ridge CTs 6630-BS-104 1,125 1,700E 2029/2030 Weston 4 Acquisition 5-BS-293 Q2 2026 165 150E 2026 Thermal Generation and Other Projects

31 Responsible Governance Appointed six new independent directors since 2020 — increasing depth of utility experience of our board of directors. $20+ million Contributed by our companies and foundations to nonprofit organizations in 2024. $332.4 million Spent with certified minority-, women-, service disabled- and veteran- owned businesses in 2024. $128.0 million Spent on energy efficiency and conservation in 2024. Commitment to Stewardship and Governance

32 73% 31% 7% 40% 43% 17% 21% 21% 3% 8% 34% 2005 2024 2030E 2032 2050 Coal Natural Gas Nuclear Renewables <2% Net carbon neutral goal Planned exit from coal Exiting Coal Electricity Supply by Fuel Type (megawatt-hours delivered to regulated utility customers)

33 Clean Energy Pilot Projects Investing in Innovation Organic Flow Battery Storage  Leading a pilot project to test a new ‘green battery’ – a form of long-duration energy storage that incorporates environmentally friendly materials  Partnering with EPRI and CMBlu Energy  Project will test battery system performance, including the ability to store and discharge energy for up to twice as long as the typical lithium-ion batteries in use today Columbia Energy Storage Project  20 MW carbon dioxide based, long duration battery project being developed at Columbia Energy Center  Partnering with Energy Dome, Alliant Energy and Madison Gas and Electric  Battery charges by converting CO2 into a compressed liquid stored under pressure. Liquid is converted back to gas to power a turbine generating electricity without emitting CO2

34 In service Total Project Capacity (MW) Investment (in millions) Wind ● Upstream 200 $307 ● Bishop Hill III 132 166 ● Coyote Ridge 97 145 ● Blooming Grove 250 389 ● Tatanka Ridge 155 240 ● Jayhawk 190 282 ● Thunderhead 300 381 ● Sapphire Sky 250 442 Solar ● Samson I 250 278 ● Maple Flats 250 431 ● Delilah I 300 462 ● Hardin III 250 406 Total 2,624 $3,929 SD IL NE KS TX OH WEC Infrastructure Portfolio

35 Project Ownership Percentage Offtake Agreement WEC Commercial Operations Bishop Hill III Wind Energy Center 90% ownership WPPI Energy – 22 years 8/31/18 Upstream Wind Energy Center 90% ownership Affiliate of Allianz – 10 years 1/10/19 Coyote Ridge Wind Farm 82% ownership and 99% of tax benefits Google Energy LLC – 12 years 12/20/19 Blooming Grove Wind Farm 90% ownership Verizon and Saint-Gobain North America – 12 years 12/8/20 Tatanka Ridge Wind Farm 86% ownership and 99% of tax benefits Google Energy – 12 years Dairyland Power – 10 years 1/5/21 Jayhawk Wind Farm 90% ownership and 99% of tax benefits Meta Platforms Inc. – 10 years 12/15/21 Thunderhead Wind Energy Center 90% ownership Verizon, GM, Ultium Cells LLC, and a Fortune 100 Company – 12 years 11/16/22 Sapphire Sky Wind Energy Center 90% ownership Microsoft Corp – 12 years 2/7/23 Samson I Solar Energy Center 90% ownership AT&T Corp – 15 years 80% on 2/24/23, 10% on 1/1/24 Maple Flats Solar Energy Center 90% ownership Verizon – 15 years 11/21/24 Delilah I Solar Energy Center 90% ownership Honda and Tesla – 15 years 12/3/24 Hardin Solar III Energy Center 90% ownership Microsoft Corp – 15 years 2/11/25 Infrastructure Investment Summary

36 Company 2025 2026 2027 Wisconsin Electric $2,775.5 $3,212.1 $4,670.5 Wisconsin Gas 213.9 257.5 296.3 Wisconsin Public Service 679.3 706.3 959.0 Upper Michigan Energy 146.3 47.1 26.7 Wisconsin Segment $3,815.0 $4,223.0 $5,952.5 Peoples Gas 289.1 512.7 680.7 North Shore Gas 34.5 53.9 57.7 Illinois Segment $323.6 $566.6 $738.4 Minnesota Energy Resources 65.4 62.8 67.3 Michigan Gas Utilities 51.0 52.2 43.2 Other States Segment $116.4 $115.0 $110.5 We Power 76.7 96.3 130.9 Bluewater 1.5 1.9 1.6 Infrastructure Investments 405.9 0.0 0.0 Nonutility Energy Infrastructure $484.1 $98.2 $132.5 Corporate and Other $23.0 $15.3 $15.6 Subtotal $4,762.1 $5,018.1 $6,949.5 ATC Investment* $512.6 $656.9 $802.0 Total WEC Capital Projection $5,274.7 $5,675.0 $7,751.5 Capital Plan Projections ($ in millions) * ATC is accounted for using the equity method; this represents WEC Energy Group’s portion of the investment.

37 Composition of Asset Base Total 2024 Average Asset Base of $30.8 Billion Note: We Power value represents investment book value for lease calculation purposes. Company Asset Base - $B % of Total Wisconsin Electric $9.0 29.2% Wisconsin Gas 2.2 7.1 Wisconsin Public Service 4.8 15.6 Upper Michigan Energy Resources 0.4 1.3 Peoples Gas 4.5 14.6 North Shore Gas 0.4 1.3 Minnesota Energy Resources 0.5 1.6 Michigan Gas Utilities 0.4 1.3 We Power 3.2 10.4 Bluewater 0.3 1.0 WEC Infrastructure 2.2 7.1 American Transmission Company 2.9 9.5 Total $30.8 100%

38 Power the Future Investments Port Washington (Natural Gas) Oak Creek Expansion (Coal/Co-Fire Gas2) Capacity1 1,090 MW 1,030 MW ROE / Equity 12.7% / 53% 12.7% / 55% 2024 Investment Book Value for Lease Calculation Purposes1 $790 million $2.4 billion Base Lease Term 25 years 30 years Base Lease Term Expiration Unit 1 – July 2030 Unit 2 – May 2033 Unit 1 – February 2040 Unit 2 – January 2041 1. All capacity and investment amounts reflect WEC ownership only. Capacity value shown in table is amount guaranteed in lease agreement. 2. Pending PSCW approval.

39 Port Washington Power the Future Lease Renewal WEPCO filed a $227 million Turbine Upgrade project at Port Washington* Three options:  Renew the lease  First Renewal is 50% of last base term payment for 7 years (Unit 1 – July 2037, Unit 2 – May 2040)  Turbine Project earns 100% of the original lease term (12.7% ROE and 53% equity ratio) from in service through end of 1st renewal period  Purchase the unit at the FMV appraisal from appraiser approved by the PSCW  Walk away We expect at this time that the renewal of the lease is the most advantageous for customers *Subject to PSCW approval.

40 National Leader in Operating Efficiency and Financial Discipline $29.69 $11.90 $16.80 $19.60 $20.00 $20.00 $23.00 $23.80 $25.60 $26.10 $50.20 $89.60 $0 $10 $20 $30 $40 $50 $60 $70 $80 $90 2024 Non-Fuel O&M per MWh* Source: FERC Form 1 Reports *For all companies, excluded 1) pensions and other employee benefits, 2) costs reported as “transmission of electricity by others” to neutralize differences in ownership of the transmission used by each utility, and 3) costs reported as “rents” within the production section to control for difference in how power plants are owned and financed. The top 11 vertically integrated electric utilities by Dec. 31, 2024 market cap W E C A V E R A G E

41 Financing Plans for 20251 $1,500 $1,045 $800 $200 - $300 $0 $200 $400 $600 $800 $1,000 $1,200 $1,400 $1,600 Holding Company Utilities & Energy Infrastructure Equity Issuances (i n m ill io n s ) Completed Financing Planned Financing Existing Facilities $2.7B net liquidity (as of Sept. 30, 2025) $3.9B 1. Amounts and timing are subject to material change based upon numerous factors, including market conditions, regulatory approvals, capital requirements and investment opportunities. 2. Includes refinancing for $620 million of senior notes and may include new junior subordinated notes or other securities with equity content. 3. Includes refinancing for $945 million of maturities. 4. Debt financing through Nov. 7, 2025 and equity issuances through Sept. 30, 2025. 2 3 4

42 Projected Financing Plans for 20261 $1,800 - $2,400 $2,600 - $3,100 $900 - $1,100 $0 $500 $1,000 $1,500 $2,000 $2,500 $3,000 Holding Company Utilities & Energy Infrastructure Equity Issuances (i n m ill io n s ) Planned Financing Existing Facilities $2.7B net liquidity (as of Sept. 30, 2025) $3.9B 2 1. Amounts and timing are subject to material change based upon numerous factors, including market conditions, regulatory approvals, capital requirements and investment opportunities. 2. Includes refinancing for $1,350 million of senior notes and may include new junior subordinated notes.

43 33% Large C&I by Segment Paper/Packaging 25% Mining/Minerals 11% Foundry (SIC 33) 9% Other Manufacturing 8% Metal (SIC 34,35,37) 7% Medical 7% Food/Agriculture 6% Education 4% Chemical 3% Printing 3% Office 2% Other 15% Balanced and Diverse Sales Mix Large C&I 33% Residential and Farm 31% Small C&I 36% 2024 Retail MWh Deliveries Mix* *Wisconsin segment includes Michigan electric and retail choice customers in the Upper Peninsula.

44 Estimated Decision Date Wisconsin (apps.psc.wi.gov)  Decision on Very Large Customer Tariff (Docket: 6630-TE-113 filed 3/31/25) Q2 2026 Illinois (icc.illinois.gov)  Decision on 2017 QIP Reconciliation (Docket: 18-0620 filed 3/20/18) 2026 Regulatory Matters

45 Regulatory Environment Wisconsin Commissioners Name Party Current Term Starts Current Term Ends Summer Strand Chair D 03/2023 03/2029 Kristy Nieto* D 04/2025 03/2031 Marcus Hawkins* D 04/2024 03/2027 Wisconsin  Governor Tony Evers (D)  Term ends January 2027  Commission  Gubernatorial appointment, Senate confirmation  Chairman: Gubernatorial appointment  6-year staggered terms Illinois  Governor J.B. Pritzker (D)  Term ends January 2027  Commission  Gubernatorial appointment, Senate confirmation  Chairman: Gubernatorial appointment  5-year staggered terms Illinois Commissioners Name Party Current Term Starts Current Term Ends Doug Scott Chair D 06/2023 01/2029 Conrad Reddick D 03/2023 01/2028 Michael Carrigan* D 02/2025 02/2030 Ann McCabe R 02/2022 01/2027 Stacey Paradis R 03/2023 01/2028 * Pending confirmation

46 Rate-Making Parameters by Company Utility Equity Layer1 Authorized ROE Wisconsin Electric 50.50%-55.50% 9.80% Wisconsin Public Service 50.50%-55.50% 9.80% Wisconsin Gas 50.50%-55.50% 9.80% Peoples Gas 50.79% 9.38% North Shore Gas 52.58% 9.38% Minnesota Energy Resources 53.00% 9.65% Michigan Gas Utilities 50.00% 9.86% Upper Michigan Energy Resources 50.00% 9.86% We Power 53.00%-55.00% 12.70% American Transmission Company 50.00% 10.48% 1. Represents the equity component of capital; rates are set at the midpoint of any range 2. Subject to PSCW approval of filed VLC tariff  Overall, constructive regulatory environments.  Earnings sharing mechanism at all Wisconsin utilities.  Wisconsin Electric - Bespoke2:  Equity layer: 57%  ROE: 10.48%-10.98%

47 Key Rate-Making Components State Illinois Minnesota Michigan Wisconsin Utility Gas Gas Electric and Gas Gas Electric Gas Pipeline Replacement Rider MGU Bad Debt Rider ✓ Bad Debt Escrow Accounting Residential Residential Decoupling ✓ ✓ Fuel Cost Recovery 1 for 1 recovery of prudent fuel costs +/- 2% band MGP Site Clean Up Recovery ✓ ✓ ✓ ✓ N/A Invested Capital Tax Rider ✓ Forward-Looking Test Years ✓ ✓ ✓ 2 years 2 years Gas Utility Infrastructure Cost Rider Surcharge ✓ Earnings Sharing WPS and WG: No sharing on first 15 bp above allowed ROE, 50/50 on next 60 bp, 100% to customers beyond 75 bp WEPCO: No sharing on first 15 bp above allowed ROE, 50/50 on next 25 bp, 100% to customers beyond 40 bp

48 Reconciliation of EPS (GAAP) to Adjusted EPS (Non-GAAP) 2015 2016 2017 2023 2024 EPS – GAAP basis $2.34 $2.96 $3.79 $4.22 $4.83 Acquisition Costs 0.39 0.01 – Integrys Earnings (0.47) Impact of Additional Shares 0.47 Tax Benefit Related to Tax Cuts and Jobs Act of 2017 (0.65) Illinois Disallowance 0.41 QIP Disallowance 0.06 Adjusted EPS – Non-GAAP Basis* $2.73 $2.97 $3.14 $4.63 $4.88** * WEC Energy Group has provided adjusted earnings per share (non-GAAP earnings per share) as a complement to, and not as an alternative to, earnings per share presented in accordance with GAAP. Adjusted earnings per share exclude, as applicable, (1) a one-time reduction in income tax expense related to a revaluation of our deferred taxes as a result of the Tax Cuts and Jobs Act of 2017; (2) costs related to the acquisition of Integrys Energy Group; (3) the results of operations of Integrys and its subsidiaries; (4) the additional shares of WEC Energy Group common stock that were issued as part of the acquisition; (5) a non-cash charge related to the ICC’s disallowance of certain capital costs; and (6) estimated losses associated with the ICC disallowance related to its review of the 2016 Qualifying Infrastructure Plant (QIP) capital investments under the QIP rider. None of these items are indicative of WEC Energy Group’s operating performance. Therefore, WEC Energy Group believes that the presentation of adjusted earnings per share is relevant and useful to investors to understand the company’s operating performance. Management uses such measures internally to evaluate the company’s performance and manage its operations. **2024 adjusted earnings per share does not add due to rounding.

49 Contact Information M. Beth Straka Senior Vice President – Investor Relations and Corporate Communications Beth.Straka@wecenergygroup.com 414-221-4639 Ashley Pless Investor Relations Analyst Ashley.Pless@wecenergygroup.com 414-221-4088