Report Date: July 28, 2026 (before market open) | Current Price: ~$44.02 (7/27/26 close)
CenterPoint enters tomorrow's print in solid shape, following a strong Q1 2026 in which the company delivered $0.56 non-GAAP EPS (vs. $0.53 in Q1 2025) and reiterated full-year 2026 non-GAAP EPS guidance of $1.89–$1.91, representing roughly 8% growth over 2025's delivered $1.76. Management explicitly said Q1 execution "positions us well for the remainder of the year" and pointed to accelerating industrial/data-center load growth as an incremental tailwind on top of the base plan.
Since Q1, CNP has continued a string of positive catalysts: a $0.01 dividend hike to $0.24/share (announced July 16, marking six consecutive years of increases), continued regulatory settlements, and a wave of sell-side price-target increases (BMO to $48, Morgan Stanley to $40, average street target near $46-$47) heading into the print, alongside one trim (KeyBanc to $46 from $47). The stock is up roughly 14% year-to-date, trading near the upper end of its 52-week range ($37.75–$45.04).
Sell-side estimates for Q2 2026 have been converging in the $0.36–$0.38 non-GAAP EPS range, with consensus revenue around $2.12 billion. That would represent roughly 24–31% year-over-year growth off the $0.29 non-GAAP EPS CNP posted in Q2 2025 — a quarter that was seasonally soft due to off-cadence capital tracker filings, storm-prep O&M timing, and modest weather headwinds. KeyCorp recently raised its Q2 estimate, one of several upward revisions into the print. For the full year, the Street is modeling EPS around $1.91 (the top of guidance), with continued high-single-digit growth (~8.9%) penciled in for 2027.
Key swing factors for the quarter: - Rate recovery cadence: New DCRF rates (Houston Electric distribution, ~$108M revenue requirement) went into effect in June, and updated TCOS transmission rates (~$36M) took effect in mid-April — both should show a fuller quarter of benefit versus Q1. The Texas Gas GRIP filing (~$62M) was also expected to hit rates in June. - O&M timing: In 2025, vegetation management spend was pulled forward into H1 ahead of hurricane season, creating a Q2 O&M drag that was expected to reverse in H2. Watch whether 2026's accelerated vegetation program (5-year to 3-year trim cycle) creates a similar or different quarter-to-quarter pattern. - Weather: Milder-than-normal weather dinged Q1 2026 by $0.02; Houston-area storm activity in Q2 (several rounds of severe thunderstorms were reported in May and June 2026) could be a modest swing factor on both revenue and restoration costs. - TEEEF drag: The temporary emergency generation units remain a headwind until they're remarketed (expected as early as fall 2026), so continued non-GAAP add-backs here are likely. - Interest expense: Higher rates on new debt issuances have been a consistent $0.03–$0.04 per-quarter drag; the $650 million convertible note issued in February should have helped offset floating-rate exposure.
The headline theme all year has been the dramatic upward revision to Houston-area electric demand. On the Q1 call, CenterPoint disclosed 12.2 gigawatts of firmly committed industrial load (up from 7.5 GW just one quarter earlier), with 8 GW of data center load expected to be energized by 2029 (up from a prior 7.5 GW target) and 3.5 GW already under construction. Management noted 3.2 GW has already secured ERCOT approval — including 2.5 GW approved in under 80 days — with the remaining ~9 GW expected to be submitted to ERCOT within weeks of the Q1 call under the new "Batch Zero" interconnection framework.
Investors should listen for: 1. Progress on the 9 GW ERCOT filing — has it been submitted/approved, and is the pace of approvals holding at 55–80 days? 2. Indiana large-load update — management flagged a potentially "transformational" large customer in Southern Indiana that could unlock ~1.5 GW of capacity via a ~$1 billion investment (simple-cycle-to-combined-cycle conversion plus transmission), delivering an estimated $250 million of customer savings over 15 years. Any signed agreement here would be a notable positive catalyst. 3. Transmission study results — CNP is refreshing its Houston-area transmission plan and expects to complete it in the second half of 2026, which management has said will translate into new capital projects to replace hosting capacity being consumed by large loads (filling a gap around 2029–2031 before new 765kV import lines come online). Any preliminary sizing here matters for the multi-year capex trajectory. 4. Demand-charge economics — management quantified roughly $6 million per month of incremental demand charges for every 1 GW of industrial load added, framed as a pure earnings/affordability tailwind since large-load customers pay for their own interconnection capex.
At the end of Q1, CenterPoint's adjusted FFO-to-debt (Moody's methodology) stood at 12.5%, reflecting temporary pressure from pulling forward debt issuances to capture favorable market conditions; management guided to reversing this and exiting 2026 at the high end of its targeted 150bp cushion. As of Q1, CNP had completed nearly 70% of its planned 2026 financing needs. A May 2026 8-K also disclosed a new $1 billion at-the-market equity program, which is worth monitoring for usage/dilution signals. A corporate AMT refund (~$150 million/year benefit) is expected to flow through later this year and was cited as effectively funding an incremental $1 billion of capex without new equity.
The pending sale of CenterPoint's Ohio natural gas LDC to National Fuel Gas Company for $2.62 billion remains on track to close in Q4 2026, subject to Hart-Scott-Rodino clearance and a PUCO notice filing. Proceeds ($1.42 billion expected in 2026, with the remaining $1.20 billion via a seller note maturing in 2027) are earmarked to help fund the accelerating Texas growth plan. This transaction continues to be excluded from non-GAAP results, so watch for updated timing/proceeds commentary and any regulatory hiccups.
Roughly 85% of CenterPoint's capital investment is recovered through trackers rather than full rate cases, which management has repeatedly cited as a de-risking factor. Looking ahead, CenterPoint plans to file combined gas rate cases in Minnesota and Indiana in Q4 2026 (combining two Indiana cases into one, explicitly designed to reduce customer bills via cost-allocation changes) — together these represent under 20% of consolidated earnings power, but timing/ROE outcomes are worth tracking.
Going into tomorrow's report, the bar is set for continued execution rather than a dramatic re-rating event: consensus is looking for roughly $0.36–$0.38 in non-GAAP EPS, full-year guidance reaffirmation at (or above) the $1.89–$1.91 midpoint, and — most importantly — updated color on the pace of Houston-area load interconnections, the Indiana large-load opportunity, and the second-half transmission capex refresh that could push the 10-year, $65.5 billion-plus capital plan even higher. With shares near 52-week highs and analyst price targets mostly in the mid-$40s to high-$40s, the stock is arguably pricing in continued good news; the key risk into the print is less about the quarter itself and more about whether management's incremental disclosures on load growth, financing efficiency (avoiding equity needs), and the Ohio sale timeline continue to support the current premium multiple and 7–9% long-term EPS growth algorithm.