Three signals ERCOT power traders may be underweighting as the summer peak passes
Weekly ERCOT load eased in late August, solar now covers nearly a third of peak demand, and a governor's order has frozen data center connections.
Weekly average load in the Electric Reliability Council of Texas for the period ending August 29, 2026 pulled back to 73.7 GW from the record-setting week ending August 22, 2026, which ran 10% above the highest equivalent week in summer 2025 and 6% above the previous all-time weekly record, according to EIA data published on Thursday (2026-09-03).7
The market spent most of August focused on Texas peak numbers. On July 22, 2026, ERCOT set a new all-time hourly peak of 91.089 GW — 6% above the previous record of 85.508 GW set on August 10, 2023 — while NYMEX Henry Hub front-month climbed to $2.837 per MMBtu on August 19 (2026-08-19) as heat forecasts extending through early September drove a rally that broke through the 50% retracement level at $2.790, per FX Empire. Henry Hub front-month had risen to $2.99 per MMBtu by September 3 (2026-09-03). The setup looked like sustained structural demand pulling gas higher.4,6
But the July 22 peak generation data complicate that picture. At the moment ERCOT hit its all-time hourly high, solar accounted for 32% of generation and gas covered 48%, EIA data show.2
Solar at nearly a third of peak output weakens the mechanical link between demand records and natural gas price pressure. The standard bull thesis connects heat to load to gas burn in a fairly direct line; a 32% solar share at the worst demand moment of the year means gas is no longer the residual supplier it was a few years ago. NERC's Summer Reliability Assessment, published on June 3 (2026-06-03), logged nameplate solar PV additions of 30.5 GW nationally, contributing an additional 16.4 GW of capacity at peak demand, alongside more than 16 GW of nameplate battery storage capacity added to the grid — resources that absorb precisely the midday and early-evening peaks that have historically generated the strongest gas bids in Texas.1
The demand growth story faces a blunter constraint. Texas Governor Greg Abbott issued an order freezing ERCOT's "Batch Zero" interconnection process for large loads. Before that freeze, Oncor executives told analysts during a Thursday (2026-08-06) earnings call that roughly 44 GW of large load projects in the company's service territory had qualified for the process.3
Forty-four gigawatts in a single utility's queue. Ascend Analytics forecast ERCOT peak demand reaching 120 GW by 2030 — growth of more than 30% above the July 22 record — but that figure already sits below ERCOT's own internal projections, with Ascend citing supply constraints as limiting growth, according to Utility Dive. The data center and industrial loads embedded in those forecasts depend on interconnection timelines that the Governor's order has now stalled.5
The record's trajectory makes the scale of the queue clearer. ERCOT's all-time hourly peak moved from 80.148 GW on July 20, 2022, to 85.508 GW on August 10, 2023, and then to 91.089 GW on July 22, 2026 — each jump tied to a specific heat event, not a continuous structural climb. Organic demand growth without large load additions adds far less per year.4
September cooling typically reduces ERCOT weekly averages through October. A second consecutive weekly load reading below the record zone, covering the period ending September 5 (2026-09-05), would reinforce the view that the seasonal peak has cleared and that NYMEX Henry Hub front-month faces headwinds from reduced Texas gas-for-power burn.7
What would reverse that read: temperatures in Texas returning to extreme levels and sustaining through mid-September, ERCOT formally reactivating the Batch Zero process and beginning to connect large loads at scale, or the solar share at peak falling sharply enough to make gas the effective residual supplier again. None of those conditions is in place on September 3 (2026-09-03).