Snapshot
Cms Energy Corp reported $2.73B of revenue in Q1 2026, up 11.6% year over year, with diluted EPS of $1.10 and an operating margin of 17.9%.
- Revenue
- $2.73B
- YoY growth
- +11.6%
- Diluted EPS
- $1.10
- Operating margin
- 17.9%
What management said
- •Whether it's our long capital runway, Michigan's top-tier regulatory jurisdiction, our ability to keep bills affordable for customers, or the strong economic growth across the state, this model works, and it works consistently.
- •It drives a premium total shareholder return, 6%-8% adjusted EPS growth with annual compounding paired with approximately 3% dividend yield.
- •On the graph to the left, what stands out is that consistent record of support, constructive outcomes we've seen across our electric rate case filings over the last several years.
- •That includes everything from critical capital investments across the grid to advanced tree trimming on a five year cycle.
- •Our track record of consistent and constructive rate case outcomes is strong.
- •We've identified that for every 1 GW of new large load, we could see capital opportunity of $2 billion-$5 billion.
- •Episodic cost savings, load growth, and energy waste reduction as further examples.
- •In our bill growth, you see on the left side of the slide, among the lowest in the country.
- •Michigan continues to make headlines and top rankings nationwide as we see new or expanding load materialize in the state and supporting 2%-3% annual sales growth.
- •This growth allows us to spread fixed costs over a larger customer base and improve affordability for all customers.
- •Our service territory is growing with manufacturing and industrial processing, bringing with it large investments, jobs, supply chains, and commercial and residential growth.
- •Before moving on, I'll just note that our track record of delivering on our financial objectives over the last two decades, irrespective of the circumstances, speaks for itself.
What went well
- •CMS Energy delivered first-quarter 2026 adjusted net income of $346 million, or $1.13 per share, comparing favorably to the same period in 2025.
- •The Commission approved over 65% of the company's ask in its most recent electric rate case and maintained the 9.9% ROE in the electric business.
- •MPSC staff recommended over 75% of the company's $240 million gas rate case ask and supported nearly 95% of the proposed gas infrastructure investments.
- •Rate relief net of investment-related expenses drove $0.11 per share of positive variance, reflecting residual benefits of last year's electric and gas rate orders and ongoing renewable projects.
- •The company executed equity forward contracts totaling roughly $495 million, significantly de-risking its planned equity needs for the year, and signed approximately 110 MW of new load contracts year-to-date, already exceeding the roughly 100 MW signed in all of last year.
- •Both Moody's and Fitch reaffirmed the company's credit ratings in March.
What went wrong
- •A significant ice storm in the electric service territory in March, bigger than the prior year's storm, drove $0.05 per share of negative variance.
- •Moody's moved the utility to a negative outlook, largely due to the size of the five-year capital investment plan relative to the timing of cost recovery, particularly for large projects with protracted construction cycles.
Guidance changes
| Metric | Period | Previous | Current | Change |
|---|---|---|---|---|
| Weather (normal-weather assumption) | Remaining nine months of 2026 | Favorable 2025 temperatures | Plan for normal weather | $0.23 per share negative variance |
| Rate relief / regulatory | Remaining nine months of 2026 | n/a | Assumes constructive gas rate case outcome plus electric order benefits | $0.24 per share positive variance |
| O&M expense (utility) | Remaining nine months of 2026 | n/a | Lower O&M via CE Way and cost reduction initiatives | $0.04 per share positive variance |
| NorthStar plus parent financing | Remaining nine months of 2026 | n/a | Solid NorthStar performance offset by parent financing/equity dilution | $0.06 to $0.13 per share positive variance |
| Equity issuance | Full-year 2026 | n/a | Plan to issue approximately $700 million aggregate; ~$495 million in forwards executed, ~$142 million settled in Q1 | On plan |
Performance breakdown
| Metric | YoY change | Reason |
|---|---|---|
| Adjusted EPS | $1.13 per share in Q1 2026, favorable versus Q1 2025 | NorthStar outperforming a soft prior-year comp plus higher rate relief net investments at the utility, partially offset by the March ice storm. |
| Weather/heating degree days | $0.01 per share favorable | Relatively normal heating degree days as a warm March and February offset a typically cold January. |
| Storm/cost category | $0.05 per share negative | An uptick in storm activity including a sizable March ice storm larger than last year's, with some positive offsets from the electric supply business. |
Earnings call themes & trends
| Topic | Previous mention | Current period | Trend |
|---|---|---|---|
| Data center / large-load pipeline | Roughly 9 GW pipeline; ~100 MW signed last year | Pipeline larger than 9 GW; ~110 MW signed year-to-date; advanced negotiations with at least two hyperscalers, finalizing one contract | growing |
| Large-load CapEx sensitivity | n/a | Every 1 GW of new large load could create $2 billion-$5 billion of incremental capital opportunity, beyond the current plan | incremental upside |
| Equity financing strategy | ~$700 million planned for 2026 | ~$700 million for 2026; averaging ~$750 million per year thereafter, more front-end loaded; equity forwards used to de-risk | front-end weighted |
| Affordability | n/a | Michigan electric bills 14th lowest in the nation, below national and Midwest averages, while investing over $24 billion over the five-year plan | stable / focus area |
Q&A summary
What is the data center opportunity now versus last quarter, and could it defer the electric rate case filing cadence?
Rochow said the pipeline is strong and larger than 9 GW, with progress on hyperscalers evaluating multiple Michigan locations and good progress on zoning. He pointed to the November large-load tariff as a strong standard, noted significant capital runway, and said annual rate cases let the company pass savings to customers, with affordability the central focus rather than deferring cases.
Any guiding principles on potential portfolio transactions, including accretion/dilution around NorthStar?
Rochow stated a long-standing company policy of not commenting on M&A. He reiterated prior framing: thermal assets like Dearborn Industrial Generation benefit from rising energy and capacity prices via bilateral contracts; renewables are solid singles-and-doubles projects with utility-like returns and safe-harbored assets in the 2028-2029 timeframe; NorthStar is about 5% of the earnings mix with the rest utility.
Status of Gaines Township and the Microsoft data center and public pushback?
Rochow described Michigan's local-government zoning process across roughly 2,800 local units, noting data centers and the company have been meeting with township and planning officials with good progress. He said elected officials are doing appropriate due diligence on property tax, zoning, land use and water, and declined to predict a date but expressed optimism.
Can you reaffirm the as-early-as-2028 online date given the Gaines Township tabling?
Rochow said project timelines are the same, with 2028 within the contracts, early electrons then ramp-up over 2029 and 2030.
What countermeasures are you considering for Moody's negative utility outlook, and how proactive is the need?
Hayes said because it is at the opco, options are more constrained than at the parent, focusing on rate-making capital structure and potentially cost of capital. The company is evaluating qualitative and quantitative measures and will likely need to educate the Commission and stakeholders over the next 12-18 months to avoid further Moody's action.
Does converting large-load opportunities reduce or increase equity needs?
Hayes said converting large load would put upward pressure on CapEx (each gigawatt adds $2 billion-$5 billion), which in turn raises financing needs including equity. The additional equity would fund growth and rate-base expansion rather than result from the load conversion itself.