Snapshot
Cms Energy Corp reported $2.02B of revenue in Q3 2025, up 15.9% year over year, with diluted EPS of $0.92 and an operating margin of 23.8%.
- Revenue
- $2.02B
- YoY growth
- +15.9%
- Diluted EPS
- $0.92
- Operating margin
- 23.8%
What management said
- •I am very pleased with the results and continue to see us well positioned for the full year and in the long term.
- •Recently on the electric side, staff filed their position in our pending rate case supporting approximately 75% of our revised and approximately 90% of our capital ask.
- •As shared in previous quarterly calls, we continue to see strong economic growth in Michigan.
- •As I highlighted in the Q2 call, we have an agreement with the data center and continue to see growth with manufacturing as well as a robust pipeline.
- •Year to date we have connected approximately 450 MW of the planned 900 MW of industrial growth in our five-year plan.
- •This growth is coming from new projects, expansion from existing customers in the areas of food processing, aerospace and defense, and advanced manufacturing.
- •These products bring jobs and supply chains, home starts, and commercial opportunities to the state and create further visibility to our 2%-3% forecasted annual sales growth over the next five years.
- •You'll note we continue to move projects into and along the pipeline, bolstering our confidence in additional growth from data centers and other diverse industries.
- •You'll also see other large data centers in the final and advanced stages of development, which speaks to the robust nature of our pipeline.
- •I continue to be confident and excited about the growth coming to our service territory.
- •The data center and manufacturing pipeline is robust and advancing, and we are well equipped to serve and meet their needs as they advance.
- •As a result of more load growth, we're focused on resource adequacy and the Clean Energy Law, which means more renewables, battery storage, and natural gas generation to meet growing demand.
What went well
- •Through the third quarter of 2025, CMS Energy delivered adjusted net income of $797 million, or $2.66 per share, comparing favorably to the first nine months of 2024.
- •A warm summer in Michigan drove $0.37 per share of positive year-to-date weather-related variance, and rate relief net of investment costs contributed $0.28 per share of positive variance.
- •The company received a final order in its Renewable Energy Plan approving an additional 8 GW of solar and 2.8 GW of wind through 2035.
- •A constructive gas rate order was received approving approximately 75% of the final ask and 95% of infrastructure investments.
- •Year-to-date the company connected approximately 450 MW of the planned 900 MW of industrial growth and signed another approximately 100 MW of contracts, with electric staff supporting roughly 75% of the revised revenue and 90% of the capital ask in the pending case.
- •The company completed virtually all of its planned 2025 financings, including settling approximately $500 million of forward equity contracts at favorable share price levels, and had credit ratings reaffirmed at the utility by S&P.
What went wrong
- •Year-to-date cost performance showed $0.04 per share of negative variance versus 2024, driven by increased vegetation management expense.
- •A $0.42 per share negative variance in the catch-all bucket was driven primarily by the planned outage of the Dearborn Industrial Generation (DIG) facility, timing of renewable projects at NorthStar, and higher parent financing costs.
Guidance changes
| Metric | Period | Previous | Current | Change |
|---|---|---|---|---|
| Weather (normal-weather assumption) | Remaining three months of 2025 | Mild 2024 Q4 temperatures | Plan for normal weather | $0.15 per share positive variance |
| Regulatory / rate relief | Remaining three months of 2025 | n/a | Constructive gas rate order effective November 1 | $0.03 per share positive variance |
| Cost (vegetation management + supplemental spending) | Remaining three months of 2025 | n/a | Ongoing vegetation management and supplemental operational/customer spending | $0.06 per share negative variance |
| Catch-all (one-time countermeasures / NorthStar) | Remaining three months of 2025 | n/a | Absence of one-time countermeasures partially offset by NorthStar renewable milestones | $0.05-$0.09 per share negative variance |
Performance breakdown
| Metric | YoY change | Reason |
|---|---|---|
| Adjusted net income / EPS (nine months) | $797 million / $2.66 per share, favorable versus first nine months of 2024 | Higher rate relief net of investment costs and favorable weather-related sales from a warm Michigan summer. |
| Weather-related sales (year-to-date) | $0.37 per share positive | Warm summer in Michigan. |
| Rate relief net of investment costs (year-to-date) | $0.28 per share positive | Constructive March electric rate order and residual benefits of last year's gas rate case settlement. |
| Operating costs (year-to-date) | $0.04 per share negative | Increased vegetation management expense from higher spending approved in the March electric rate order and the reliability roadmap. |
| Catch-all category (year-to-date) | $0.42 per share negative | Planned DIG outage, timing of NorthStar renewable projects, and higher parent financing costs. |
Earnings call themes & trends
| Topic | Previous mention | Current period | Trend |
|---|---|---|---|
| Data center / large-load pipeline | One agreement discussed in Q2 | Three large data centers in final stages (up to 2 GW); the Q2 opportunity is up to 1 GW beginning early 2030; large load tariff order expected November 7 | advancing |
| Renewable Energy Plan | Pending | Final order approving additional 8 GW solar and 2.8 GW wind through 2035, a key input to the mid-2026 IRP | approved |
| Capital plan / backlog | $20 billion five-year plan | $20 billion plan with over $25 billion of additional opportunity knocking on the door; expects to dip into all three buckets in the Q4 plan refresh | growing |
| Economic development / load growth | n/a | ~450 MW of planned 900 MW connected year-to-date plus ~100 MW newly signed; supports 2%-3% annual sales growth | on track |
| Campbell plant | n/a | Operating under Department of Energy orders with costs treated as a regulatory asset, shared across nine MISO North/Central states; Michigan customers to be refunded | cost recovery path established |
Q&A summary
What is the timing on the large load tariff and the opportunity behind it?
Rochow said three large data centers are in final stages representing up to 2 GW. The large load tariff order is expected November 7 and is a key gating item; the Q2-referenced opportunity at the bottom of the funnel should move forward in short order once the tariff is in place, with the other two expected to follow. He noted the projects have land, zoning, and worked-through red lines.
How quickly could the $25 billion-plus backlog be folded into the plan?
Rochow said more detail comes in the Q4 call, anticipating more electric reliability spending aligned with the Liberty Audit and reliability roadmap, an approved Renewable Energy Plan adding 8 GW solar and 2.8 GW wind through 2035 with safe-harbor incentives, and the mid-2026 IRP filing leading to battery storage and natural gas capacity filtering into the five-year plan.
Will the gas plant in the next IRP be simple cycle or combined cycle?
Rochow said the company continues to work through it, needing both battery and natural gas capacity for retiring facilities and load growth; adding data centers would grow the need, and the company is evaluating the simple cycle versus combined cycle mix.
What is the offsetting factor that keeps incremental CapEx from raising the growth trajectory?
Hayes cited compounding off actuals, the difficulty of consistently delivering toward the high end of 6%-8% (effectively 7%-8%), and the need to build in contingency given the company is not decoupled, lacks a permanent service restoration deferral mechanism, and faces intensifying storm and weather risk.
How does the Campbell plant work from an accounting and cost-recovery perspective?
Rochow and Hayes said all costs of operating the Campbell units are treated as a regulatory asset that amortizes as recovery is received. Costs and offsetting revenue are spread across nine MISO North and Central states per the FERC-approved 206 complaint, with Michigan customers refunded for their already-contributed share, keeping them held harmless.
What is the self-build versus PPA mix for the Renewable Energy Plan?
Rochow said safe-harboring favors more renewables in the first five years (out to 2029), competitively bid with a good portion of self-build, and he is open to PPAs as a capital-light way to earn roughly 9%. Hayes said the $10 billion estimate assumes about 50/50 owned versus PPA for solar and closer to 100% owned for the 2.8 GW of wind.