Why Texas's solar surge masks an infrastructure bet that deregulation alone cannot keep

In late July 2024, Texas's grid operator ERCOT hit record electricity demand on consecutive days and did not issue a single conservation notice. The outcome was not a near-miss, as past summers had been; it was a margin of safety. A Times of India report credits the shift to solar deployment: a 20,000 megawatt buffer that kept the system from buckling.^[1]

That is real. The underlying trend is faster than the headline allows. Between June and August 2024, solar provided nearly 25 percent of Texas's peak demand power during the hottest hours.^[1] In the first nine months of 2025, utility-scale solar alone generated 45 terawatt-hours, a 50 percent jump from the same months in 2024.^[2] Texas now installs solar faster than any other state; solar accounted for 8 percent of all generation in 2024, surpassing nuclear for the first time.^[4] The grid is, by the numbers, more resilient in daylight hours than it was three years ago.

The mechanism at work is simple and incomplete: deregulation rewards speed over structure. In Texas's competitive market, solar and battery installations attract private capital because the returns are front-loaded and the regulatory path is clear. There is no utility monopoly extracting a rate base return; there is no commission approval lag. A firm builds a solar farm, sells power into ERCOT's market, and pockets the edge between generation cost and the spot price. Scarcity raises that price. Texas's demand growth, 5 percent year-over-year in 2025, driven by data centers and population inflow, guarantees scarcity peaks. The solar buildout is not altruism. It is arbitrage. And it works, so long as the sun is high and the batteries are charged.

The vulnerability lives in the rest. By 2032, ERCOT forecasts demand will reach roughly 175,000 megawatts, nearly double the current peak.^[8] Regulators have said they are confident solar and battery storage will meet that demand, but they have also cautioned that the state needs more natural gas generation to cover the hours when solar is not producing.^[8] That is the trap hidden in the deregulated model: competitive markets attract capital for the lowest-cost marginal unit (solar, at near-zero fuel cost), but they do not guarantee the backbone assets, transmission, dispatchable gas plants, or multi-hour storage, that keep the grid standing when demand is high and renewables are dark. ERCOT has no utility balance sheet to bet on a ten-year infrastructure play. It has competing generators, each playing for a quarter. Transmission, historically built by monopolies over decades, is now a snarled permitting problem. Battery storage, which could bridge solar's intermittency, is capital-intensive and lacks long-term revenue certainty under Texas's energy-only market design.

The February 2021 blackout that killed hundreds happened not because Texas had too much wind, but because it had underinvested in winterization, spare capacity, and transmission. The grid failed under stress, not shortage of fuel. Solar's surge into peak summer demand does not solve that failure mode. A heat dome that flattens solar output during evening demand ramp, a low-probability but rising-likelihood event as climate volatility increases, would expose the same inadequacy: a system optimized for cost, not resilience, with no operator whose income rises if the lights stay on when conditions are hard.

The concrete alternative is visible in Britain and Hawaii. Both jurisdictions have moved away from deregulation's single-metric purity (lowest cost at the margin) toward a revenue-cap model that ties utility income to reliability and resilience outcomes. Hawaii's 2020 framework, adapted from Britain's RIIO model, sets multi-year revenue targets, penalizes utilities for missed reliability standards, and rewards them for beating targets, symmetrically, so the risk cuts both ways. A utility that lets SAIDI (average outage minutes per customer per year) creep up loses revenue. One that hardens the grid and brings it down gains revenue, capped. That structure creates incentive to build and maintain the backbone assets that solar alone will not. Texas could move toward performance-based regulation in ERCOT's next market redesign, linking generator and grid operator income to forward-looking adequacy metrics (multi-hour battery depletion, transmission congestion, reserve margin under weather stress) rather than spot-price arbitrage alone. That is not a rollback of deregulation. It is a completion of it: a market that prices reliability and has operators who profit from delivering it.