CenterPoint Energy (CNP) Q2 2026 beats: Houston load queue swells to 14 GW, capex plan lifted $1.2bn

CenterPoint Energy, Inc. (NYSE: CNP), the Houston-based investor-owned electric and gas utility, delivered a materially stronger second quarter of 2026 than the prior-year comparable, reporting GAAP net income of $244 million or $0.37 per diluted share and non-GAAP earnings of $0.40 per diluted share, both meaningfully ahead of the $0.30 and $0.29 respectively posted in the second quarter of 2025.

Alongside the results, the company disclosed that it has submitted more than 17 gigawatts of large-load projects through the Electric Reliability Council of Texas (ERCOT) Batch Zero process, of which approximately 14 gigawatts are expected to be eligible as base load or studied load, a queue equivalent to more than a 65 percent addition on top of the current Houston Electric peak system demand of 21 gigawatts. Management raised the ten-year capital investment plan by $1.2 billion to $66.7 billion covering 2026 through 2035 without lifting its current equity financing guide, and reiterated its 2026 non-GAAP EPS guidance range of at least the midpoint of $1.89 to $1.91, which at the midpoint would represent roughly 8 percent growth over 2025 delivered non-GAAP EPS of $1.76. The central tension for shareholders is now whether the Houston load queue converts into energised, rate-recovering megawatts on the timeline management has framed, at a valuation that has already moved close to its 52-week high.

How much of the earnings beat came from underlying regulated growth rather than one-off drivers?

The composition of the quarter matters more than the headline number for a regulated utility. According to the company’s own bridge, growth and regulatory recovery contributed roughly $0.10 per share of favourable variance versus the second quarter of 2025, operations and maintenance discipline added another $0.02 per share, and a further $0.01 per share came from other items linked primarily to amortisation of deferred equity from previous storm securitisations, partially offset by higher other taxes and equity dilution. Working the other way, weather and usage cost roughly $0.01 per share and higher interest expense cost another $0.01 per share. Stripped of the ZENS mark-to-market noise, divestiture accounting and the temporary emergency electric energy facilities (TEEEF) treatment following removal of certain units from the rate-regulated business, the underlying quarter reflects an accelerating rate base earning against a broadly disciplined cost line, rather than a mix-driven result. That is the pattern investors expect from a regulated utility guiding to high-single-digit EPS growth, and it strengthens the case that the reiterated 2026 range is not front-loaded.

For the six months ended June 30, 2026, GAAP EPS was $0.84 and non-GAAP EPS was $0.96, giving management roughly half a year of runway to deliver the remaining approximately $0.94 needed at the midpoint of guidance. That trajectory looks achievable if the second-half regulatory recovery and load-related capital investment continue to flow through at the pace implied by the first half, though rising interest expense remains a visible drag that will need to be offset by rate base growth rather than any one-time item.

Why does the 14 gigawatt Batch Zero queue matter more than the headline capex increase?

The single most consequential disclosure in this release is not the $1.2 billion capex uplift. It is the composition of the Batch Zero queue. CenterPoint submitted over 17 gigawatts of large-load projects, and roughly 14 gigawatts are expected to qualify as base load or studied load. Set against Houston Electric’s current 21 gigawatt peak system demand, that queue represents a potential increase of more than 65 percent, phased through 2031. For a regulated transmission and distribution utility, load growth of that magnitude is the mechanism by which the ten-year plan actually gets funded and earns a return. Every incremental gigawatt that reaches energisation adds interconnection revenue, unlocks base rate growth through utilisation of both existing capacity and new investment, and, through fixed-cost dilution, is projected by management to reduce residential and commercial delivery charges cumulatively by at least $5 billion over the next decade.

The important qualifiers are that the 14 gigawatts is an eligibility figure inside a queue process, not an approved connection schedule, and that ERCOT will ultimately determine how the load is allocated between base and studied categories. That distinction affects both the energisation timeline for individual projects and the timing of associated capital deployment. Management has framed the opportunity as executable rather than aspirational, citing existing system capacity, prior large-load connection experience and targeted incremental investment, but the operating question over the next four to six quarters is how quickly ERCOT completes its determinations and how much of the queue converts to firm interconnection agreements.

Does raising the ten-year capex plan without lifting the equity guide add up?

The $1.2 billion increase to a $66.7 billion ten-year plan is directionally modest, roughly 1.8 percent, but the more interesting element is the financing framing. Management explicitly stated it did not need to increase its current equity financing guide to accommodate the higher plan, implying that operating cash flow, targeted debt issuance, capital recycling and previously announced securitisation and forward equity tools are expected to absorb the incremental capital. This is consistent with the company’s existing balance-sheet toolkit, which includes the $600 million 2.875 percent convertible senior notes due 2029 priced in February 2026, and the pending sale of the Ohio natural gas local distribution business.

For shareholders, the practical read-across is that management believes it can carry incremental rate base without materially accelerating dilution beyond what was already communicated. That is a meaningful stance, but it is contingent on three moving parts: the closing terms of the Ohio LDC divestiture, the pace at which the Houston load queue converts into recoverable investment, and the absence of any credit rating action that would tighten the debt window. Any one of those slipping would force a reassessment of the equity assumption, so the “no equity increase” line is best read as a policy commitment for now rather than a structural conclusion.

How resilient is the 2026 non-GAAP EPS guidance in the second half?

Reiterating rather than raising guidance at the midpoint of the year is a considered signal. On the positive side, the first-half non-GAAP delivery of $0.96, more than half of the $1.89 to $1.91 range, and the observed strength in growth and regulatory recovery are supportive. On the cautious side, management appears to be preserving room for continued interest expense pressure and the residual mechanical impact of divestiture-related dilution, particularly around the Ohio LDC sale process and TEEEF fleet reductions. Weather, always a wildcard for a Texas-anchored electric business heading into peak cooling months, is another reason not to raise midway through the year.

The absence of a guidance raise should not be interpreted as caution about the underlying business. It is more consistent with a management team that prefers to raise once, later, with visibility on second-half regulatory outcomes and load-growth progress, than to raise now and adjust again.

What is the current market pricing into CenterPoint’s execution story?

CenterPoint shares have traded within a 52-week range of roughly $36.60 to $45.22, and closed at $44.56 in the session immediately preceding the Q2 print, near the top of that band. Recent broker actions have been mixed rather than uniformly bullish: BMO Capital reiterated a buy with a trimmed price target to $47 from $48, KeyBanc kept a buy while lowering to $46 from $47, Morgan Stanley raised its target to $40 from $39 with a hold rating, BofA lowered to $43 from $44, and Wells Fargo maintained a buy view. The consensus twelve-month target around $45 to $46 sits close to the current spot price, which suggests that Wall Street has already given management credit for meaningful load growth and rate base expansion, and is now waiting for confirmation catalysts.

For a lower-beta regulated utility, this is a valuation that assumes the growth story executes. It does not offer a large margin of safety if Batch Zero timelines slip, if the Public Utility Commission of Texas takes a more challenging line on future rate cases connected to Hurricane Beryl aftermath, or if the Ohio LDC sale closes on terms that require more incremental equity than the current guide implies. Conversely, if ERCOT allocates a supportive share of the 14 gigawatts as base load with faster energisation, and rate cases in Indiana, Minnesota and Texas resolve constructively, there is scope for the market to reset the multiple higher through 2027.

Where does the Ohio LDC divestiture and portfolio focus fit into the investment thesis?

The announced sale of the Ohio natural gas local distribution business, together with the earlier completed divestiture of the Louisiana and Mississippi natural gas LDC operations in 2025, continues to sharpen CenterPoint’s regulated footprint into a smaller number of higher-growth jurisdictions, principally Texas, Indiana and Minnesota. For the six months ended June 30, 2026, non-GAAP adjustments included $0.05 per share related to mergers and divestitures and a further $0.06 per share for TEEEF impacts, indicating that portfolio simplification is still working through the reported numbers.

Strategically, exiting Ohio removes a subscale gas business and frees management attention and balance-sheet capacity for the Houston-centred load growth cycle, which is where the strongest capital allocation opportunity now sits. The value question is whether proceeds and any associated seller-note structure are deployed at returns above the capital cost of the disposal, and whether the remaining gas businesses in Indiana, Minnesota and Texas continue to earn constructively through their respective regulatory frameworks.

What will determine whether CenterPoint’s current valuation is adequately backed by execution?

The Q2 2026 print reinforces the argument that CenterPoint has translated its Houston load-growth story into visible earnings momentum without yet extending its equity ask. What has improved is the size and specificity of the interconnection queue and the pace of underlying regulated earnings. What remains unresolved is how much of the 14 gigawatt pool ERCOT approves as base load and how quickly those projects energise. The next measurable proof point will be the third quarter print, followed by ERCOT Batch Zero determinations and the closing terms of the Ohio LDC sale, all of which will collectively test whether the current valuation is adequately backed by execution.

How do CenterPoint’s Q2 2026 numbers, Batch Zero queue and capex uplift fit together for shareholders?

• CenterPoint Energy reported second quarter 2026 GAAP EPS of $0.37 and non-GAAP EPS of $0.40, compared with $0.30 and $0.29 in the second quarter of 2025.
• Growth and regulatory recovery drove approximately $0.10 per share of favourable year-on-year variance, indicating underlying rate base performance rather than one-off drivers.
• The company submitted more than 17 gigawatts of Batch Zero projects through ERCOT, with about 14 gigawatts expected to qualify as base or studied load, a potential 65 percent increase over Houston Electric’s current 21 gigawatt peak system demand.
• The ten-year capital investment plan was raised by $1.2 billion to $66.7 billion covering 2026 to 2035, without increasing the current equity financing guide.
• Full-year 2026 non-GAAP EPS guidance reiterated at least the midpoint of $1.89 to $1.91, which would represent roughly 8 percent growth over 2025 delivered non-GAAP EPS of $1.76.
• First-half 2026 non-GAAP EPS of $0.96 represents more than half the guidance range, positioning the second half for continued growth-and-recovery driven delivery.
• Management estimates the new large-load connections could reduce Houston Electric residential and commercial delivery charges cumulatively by at least $5 billion over the next decade.
• Shares closed at $44.56 before the release, close to the top of a 52-week range of roughly $36.60 to $45.22, with consensus twelve-month price targets clustered around $45 to $46.
• Ohio natural gas LDC divestiture remains pending and continues to sharpen portfolio focus on Texas, Indiana and Minnesota, aided by prior LDC sales completed in 2025.
• Key next catalysts include ERCOT determinations on Batch Zero allocations, closing of the Ohio LDC sale, and regulatory outcomes in ongoing Texas rate proceedings linked to storm cost recovery.