Snapshot
Cms Energy Corp reported $1.84B of revenue in Q2 2025, up 14.4% year over year, with diluted EPS of $0.66 and an operating margin of 17.2%.
- Revenue
- $1.84B
- YoY growth
- +14.4%
- Diluted EPS
- $0.66
- Operating margin
- 17.2%
What management said
- •Our investment thesis: robust and solid, continuing our track record of industry-leading results.
- •This load is incremental to our plan and part of the 9 GW pipeline that we have been working to locate in our service area.
- •We continue to see positive momentum with data centers within the 9 GW pipeline and expect additional progress once we finalize the data center tariff.
- •In addition to load growth from data centers, Michigan is on the move.
- •As I shared in Q1, we continue to see strong housing starts, alterations, as well as upgrades and relocations, all signs of positive growth among residential and commercial customers.
- •What we know to be true is that growing demand, like I shared on the previous slide, enables longer-term cost savings for our customers.
- •These de-risk $4.5 billion of capital, the renewable portion of the five-year plan at the utility.
- •Again, this business makes up approximately 5% of the earnings mix, so it is small, with the majority of the growth at Dearborn Industrial Generation, or DIG, with energy and capacity sales.
- •As we move forward, we'll continue to evaluate the need for capital across the business, as we always do.
- •The ability and willingness to shift capital to utility investments that benefit our customers.
- •It is worth noting that the weather outlook in our service territory remains quite good for the balance of the summer.
- •Given our strong year-to-date performance, particularly in the second quarter, we remain confident in our ability to deliver on our full-year financial objectives to the benefit of all stakeholders.
What went well
- •Through the first half of 2025, CMS Energy delivered adjusted net income of $518 million, or $1.73 per share, comparing favorably to the same period in 2024.
- •The company announced an agreement with a new data center expected to add up to 1 GW of load, incremental to the plan and part of the 9 GW pipeline.
- •Favorable second-quarter weather, largely in June, plus a relatively normal Q1 winter provided an aggregate $0.32 per share of positive variance.
- •The commission granted a service restoration expense deferral in June, enabling a regulatory asset for the substantial costs from the March-April storm.
- •The company completed the vast majority of its 2025 financing plan, executed approximately $350 million of equity contracts de-risking about 70% of planned equity needs, and had credit ratings reaffirmed by Moody's in May.
- •The One Big Beautiful Bill Act positions the company's renewable projects to receive full production and investment tax credits with transferability through 2029, de-risking $4.5 billion of capital.
What went wrong
- •Cost trends showed $0.04 per share of negative variance versus 2024, driven largely by increased vegetation management.
- •A negative variance of $0.27 per share in the catch-all bucket was driven primarily by the planned outage of the Dearborn Industrial Generation facility, plus back-end-weighted NorthStar tax benefits, financing activity, and slightly lower non-weather sales volumes.
Guidance changes
| Metric | Period | Previous | Current | Change |
|---|---|---|---|---|
| Weather (normal-weather assumption) | Remainder of 2025 | Mild Q4 2024 temperatures | Plan for normal weather | $0.11 per share positive variance |
| Regulatory / rate relief | Remainder of 2025 | n/a | Electric rate order benefits plus expected constructive gas rate case outcome | $0.18 per share positive variance |
| O&M expense (utility) | Remainder of 2025 | n/a | Lower O&M via CE Way cost performance | $0.01 per share positive variance |
| Catch-all (one-time countermeasures / sales / financing) | Remainder of 2025 | n/a | Absence of 2024 one-time countermeasures plus conservative sales and parent financing assumptions | $0.14-$0.20 per share negative variance |
| Tax credit transfers | Five-year plan | n/a | Well positioned to execute approximately $700 million of tax credit transfers | n/a |
Performance breakdown
| Metric | YoY change | Reason |
|---|---|---|
| Adjusted net income / EPS (first half) | $518 million / $1.73 per share, favorable versus first half 2024 | Absence of prior-year unfavorable weather and continued constructive regulatory outcomes. |
| Weather-related variance (year-to-date) | $0.32 per share positive | Favorable Q2 weather largely in June plus a relatively normal Q1 winter. |
| Rate relief and investment-related expenses (year-to-date) | $0.09 per share positive | Constructive electric rate order earlier in the year and the gas rate case settlement in the second half of 2024. |
| Cost trends (year-to-date) | $0.04 per share negative | Increased vegetation management in accordance with the electric reliability roadmap. |
| Catch-all category (year-to-date) | $0.27 per share negative | Planned outage of the Dearborn Industrial Generation facility, back-end-weighted NorthStar tax benefits, financing activity, and slightly lower non-weather sales volumes. |
Earnings call themes & trends
| Topic | Previous mention | Current period | Trend |
|---|---|---|---|
| Data center / large-load pipeline | 9 GW pipeline being worked | Agreement for up to 1 GW data center signed (incremental); 9 GW pipeline continues to fill with over 200 non-data-center customers; conversions expected after the data center tariff | advancing |
| Integrated Resource Plan opportunity | n/a | Early estimate of an additional $5 billion of opportunity outside the five-year plan, primarily capacity (storage and gas); described as an early number that could be higher | emerging upside |
| One Big Beautiful Bill Act impact | n/a | Renewable projects positioned for full PTC/ITC and transferability through 2029, de-risking $4.5 billion of utility capital; NorthStar renewables safe-harbored through 2027 with some 2028 options | de-risked |
| Capital backlog | n/a | Greater than $25 billion of investment opportunity above and beyond the five-year plan | large / growing |
| Affordability | n/a | Customer utility bill roughly 3% of total expenses (share of wallet), down 150 basis points from a decade ago, with bills below the national average | improving |
Q&A summary
Can you elaborate on the 1 GW data center ramp and how it fits the resource mix?
Rochow said the team converted part of the 9 GW pipeline with an agreement where the counterparty committed significant capital for materials, equipment, and final design. Early megawatts show up in 2029 or 2030 with the ramp rate still being determined. Because the company is currently long on capacity and already building renewables and storage, it has flexibility, with willingness and preparation to build out gas capacity to serve the load.
How is the 9 GW pipeline evolving and when would it materialize?
Rochow said the 9 GW pipeline continues to fill and is conservative relative to other public documents. Some customers are still exchanging terms and red lines, with the data center tariff as a next stage gate that should enable additional conversions; the pipeline includes over 200 non-data-center manufacturing customers.
How does the 1 GW data center interact with the $5 billion of IRP CapEx upside?
Rochow said the Q4 call will update grid, economic development, and REP renewables numbers, and OBBBA is pulling developer projects forward, enabling transfer arrangements and FCM PPAs. The $5 billion-plus reflects what is needed today for 2%-3% sales growth, plant retirements, and replacing a large PPA expiring in 2030; the 1 GW data center is incremental and would push that number up.
How do you feel about the gas case and the ability to settle it?
Rochow said the company is in a great spot with 80% of the revised ask and 95% of capital approved by staff, remains open to settlement, expects a PFD in August, and is comfortable going to a fully adjudicated order.
Is there an opportunity to de-risk 2026 equity?
Hayes said the company will consider front-half 2026 funding needs alongside second-half 2025 needs and may pull ahead financing in an efficient transaction this year, keeping all options on the table given a good funding environment.
What is the status of NorthStar and DIG given the OBBBA and executive order?
Rochow said NorthStar is about 5% of the earnings mix with most growth at DIG via energy and capacity sales; renewables are small, typically one to two solar projects a year with utility-like returns. NorthStar renewables are safe-harbored through 2027 with some 2028 options, many already contracted, and the company is willing to shift capital to utility investments.