CenterPoint Energy (CNP) Q1 FY26 earnings call: guidance and Q&A

How much of the 12 GW committed load is already in the capex plan versus incremental upside, and what gates inclusion?

In ERCOT, customers pay for interconnection modifications, so the 12.2 GW is not a direct capex driver. Two tailwinds: ~$6M/month of demand charges per 1 GW of industrial load (earnings + affordability), and indirect need to replace system capacity, which becomes incremental transmission projects landing in the H2 2026 plan update.

“for every 1 gigawatt of industrial load that we add to our system, it's about $6 million a month of incremental demand charges”

asked by Shahriar Pourreza · answered by Jason Wells

How is CNP using ERCOT's large new demand forecast — supportive of Houston growth or a driver of incremental wires investment?

CNP is disciplined about what it submits to ERCOT (~3.6 GW under construction submitted, consistent with 3.5 GW actively committed), with 9 GW more filing soon. The real opportunity is replacing capacity for future growth (H2 2026 update with new projects and dollars) plus the 765 kV buildout as a medium/longer-term tailwind.

“the growth is fantastic and the fact that it provides significant customer affordability benefits by effectively spreading the fixed cost of our system out over a much larger customer base”

asked by Shahriar Pourreza · answered by Jason Wells

What is the physical and dollar investment opportunity in Indiana if the large-load customer is landed?

Existing capacity plus a MISO-queue transmission project plus converting the simple-cycle CT to combined-cycle unlocks at least 1.5 GW, sized at ~$1 billion of incremental capex (not several billion), all within 2027-2029, with further upside for additional large-load customers.

“I would think about this as more around about $1 billion opportunity as opposed to several billion dollars... definitely within '27, '28, '29.”

asked by Steven Fleishman · answered by Jason Wells

Are CNP's numbers consistent with what ERCOT reported last week, or is there a bigger number in ERCOT's total?

CNP's large-load submission in that ERCOT process was ~4 GW (actively constructing). Separately it filed a large-load study of a bit more than 11 GW not picked up in ERCOT's tables. Today's update, including the 9 GW filing soon, is incremental to what ERCOT reported.

“Our total submission as part of that process for large loads was roughly 4 gigawatts... we also filed a large load study... a little bit more than 11 gigawatts.”

asked by Steven Fleishman · answered by Jason Wells

How do credit metrics trend through 2026 and where will FFO/debt exit the year?

A function of timing: 70% of 2026 financing done, plus the corporate AMT benefit ends ~$150M/year of cash taxes (refund in coming months) with additional prior-period recoveries, giving confidence to exit at the high end of the 150 bps Moody's cushion.

“We'll have the opportunity to no longer be a cash taxpayer, which was previously on the order of roughly $150 million a year.”

asked by Jeremy Tonet · answered by Christopher Foster

What is happening with traditional large-load demand in the Gulf Coast/Houston area?

Growth is driven by both advanced manufacturing (chips-adjacent equipment, life sciences — heavy power users that run their own data centers) and data centers, plus continued energy/energy-export activity. Management stressed the diversity of drivers and sees no slowdown.

“the diversity of economic and load growth drivers is really what sets this region apart. We don't see any slowdown”

asked by Jeremy Tonet · answered by Jason Wells

What is the penetration and impact of battery storage in CNP's territory?

Significant battery investment has smoothed ERCOT summer peak pricing. Of the ~9 GW of generation connecting, it is largely solar and batteries, with solar projects rushing to qualify for tax credits before expiry and co-locating batteries. Batteries help keep energy costs low for at least the next couple years, with gas development helping after credits expire.

“we continue to see batteries as effectively a tailwind to keeping energy costs low for customers for at least the next couple of years”

asked by William Appicelli · answered by Jason Wells

Is the 8 GW energized by 2029 the same 8 GW previously targeted for year-end 2028, i.e. a one-year slip?

Foster clarified the prior 7.5 GW is now 8 GW 'by the end of 2028' (apples-to-apples), while the firmly committed top-line number rose to 12.2 GW. This conflicts with the prepared-remarks/Slide 4 phrasing of '~8 GW by 2029.'

“that number is now going to 8%. And it's by the end of 2028 is the way to think about it.”

asked by Anthony Crowdell · answered by Christopher Foster

Rough capex needed per incremental GW beyond the 10 GW existing capacity, and net customer impact?

Can't size a per-GW dollar figure because each project is unique (import line length, intra-regional lines, system stability). Net effect is further customer benefits — economic development is the single biggest affordability lever; rates have been held roughly flat since 2014.

“the single biggest lever for affordability of utility service is economic development”

asked by Andrew Weisel · answered by Jason Wells

Are lower cash taxes enough to reduce the ~$4B common equity plan, and was the convertible already assumed?

The convertible reduced near-term floating-rate pressure. The AMT benefit (~$150M/year retained plus refund) equates to adding ~$1B of capex with no incremental equity — so there is capacity to add capex without more equity.

“that can provide us the equivalent of adding an incremental $1 billion of CapEx to the plan with no incremental equity”

asked by Andrew Weisel · answered by Christopher Foster