ERCOT Just Set a 91,308 MW All-Time Peak. Here Is What It Means for Your 2027 Texas Commercial Transmission Bill.

What happened

ERCOT posted a preliminary all-time system peak of 91,308 MW at approximately 5 p.m. Central on Wednesday, July 22, 2026, according to preliminary grid data reported by Utility Dive and S&P Global. The prior all-time record was 85,508 MW, set in August 2023, so the new mark is roughly 6.8 percent higher. The record was actually broken twice inside 48 hours, with a lower preliminary peak on Tuesday, July 21, before the higher print on July 22.

Grid conditions during the peak were, in operational terms, unremarkable. ERCOT did not call an Energy Emergency Alert or a conservation appeal, and reserves stayed above roughly 10,000 MW at the peak. The July 22 print also landed slightly below ERCOT's own 2026 Summer Weather and Operations Outlook, which had forecast a peak near 92,211 MW. In short: a record load, absorbed without an emergency posture, at the top end of a forecast the grid operator already published in May.

Impact on commercial electricity buyers in Texas

For a commercial buyer, the operational stability of the event is the least interesting part. The important part is what a 91,308 MW summer peak does to your 2027 transmission bill. There are two channels we are watching.

1. 4CP allocation exposure. Under the ERCOT 4CP (Four Coincident Peak) methodology, transmission service providers allocate wholesale transmission costs to each transmission-connected load based on that load's average demand during the four highest 15-minute ERCOT system intervals in June, July, August, and September. Those four half-hours from summer 2026 will set the transmission cost allocation factors that show up on 2027 invoices. The July 22 interval is now a strong candidate to be one of those four. If your facility was drawing significant load at 5 p.m. Central on July 22, that draw will help price your 2027 transmission line item, even if the rest of your usage is unchanged.

2. Directional pressure on transmission charge components. A higher system peak, all else equal, spreads a similar pool of ERCOT-allocated transmission costs across a higher denominator, but individual facility charges rise or fall based on where each load sits relative to the peak. Buyers with load coincident to the July 22 print should expect their share of the 2027 allocation to move up, not down. We do not publish specific dollar-per-kW figures because the final 2026 4CP set is not settled until after September, and the 2027 tariff filings determine the rate. What we can say directionally: a new all-time summer peak is not a reason to expect softer transmission charges in 2027.

3. Contract term timing. Across our 721-plan active TxCP catalog as of the July 27, 2026 refresh, the mix of 12, 24, and 36-month terms means many buyers signing this fall will lock in a supply-only rate that sits alongside a transmission rider they cannot control. If you are shopping now, the peak reinforces the case for reading the transmission and delivery charges on the EFL as carefully as the energy rate itself.

The 4CP 91K Reality Check

We built a short, buyer-side decision framework to make the July 22 event actionable. Call it the 4CP 91K Reality Check: three questions to answer before you sign your next Texas commercial supply contract.

The 4CP 91K Reality Check (checklist)

Are we transmission-cost-allocated under 4CP at all? Not every commercial account is. Large transmission-connected loads and many mid-sized C&I meters are; small commercial accounts are often billed a fixed transmission rider by the TDU. Ask your REP or broker for a written answer, not a shrug.
Do we know our metered demand during the July 22, 5 p.m. Central interval? If you have interval data, pull it. If you do not, your REP has it. That single number is the leading indicator of your 2027 transmission exposure.
Do we have a plan for the remaining 4CP months? August and September are still live 4CP months. There is time to move discretionary load, pre-cool, run onsite generation during forecast peak windows, or lean on demand-response programs before the 2026 4CP set is locked.

What you should do

Confirm your 4CP status with your current REP or broker in writing. Get the exact rate schedule and confirm whether transmission is a pass-through 4CP allocation or a fixed rider.
Request your July 22, 5 p.m. Central interval demand from your REP or from your TDU meter portal (Smart Meter Texas for Oncor, CenterPoint, AEP, and TNMP customers).
Model your August and September peak-hour operations. ERCOT typically peaks between 3 p.m. and 6 p.m. Central on the hottest weekdays. Identify which loads can shift and which cannot.
Enroll in a demand-response program if you qualify. Emergency Response Service (ERS) and load resource participation can offset both bill exposure and peak coincident demand.
Revisit your contract term. If your current supply agreement expires between now and mid-2027, treat the 2027 transmission line item as an unknown and negotiate accordingly. Compare current shortlist options against your baseline in the TxCP plans database.

Questions to ask your REP or broker

Am I on a 4CP transmission cost allocation or a fixed transmission rider? Please confirm in writing with the tariff citation.
What was my metered demand during the July 22, 2026, 5 p.m. Central 15-minute interval?
What was my 2025 4CP number, and how does it compare to my current 2026 4CP-to-date average?
Which demand-response programs am I eligible for, and what is the enrollment deadline for the August and September peak windows?
How will the July 22 record influence the transmission charge line item on my next contract renewal quote?

Frequently Asked Questions

Does the July 22, 2026 ERCOT peak automatically raise my 2027 transmission bill?

Not automatically, but it raises the probability. The July 22 interval is now a strong candidate to be one of the four 15-minute intervals in the 2026 4CP set. Your 2027 transmission cost allocation is based on your average demand across those four intervals, so if your facility was pulling meaningful load at 5 p.m. Central on July 22, your 2027 allocation factor will likely move up.

What is 4CP and why does one summer half-hour matter so much?

4CP stands for Four Coincident Peak. It is the ERCOT methodology that assigns wholesale transmission costs to transmission-connected loads based on each load's average demand during the four highest 15-minute ERCOT system-wide intervals in June, July, August, and September. Because those four intervals price 12 months of transmission charges, each one carries outsized weight for buyers subject to 4CP allocation.

Was the grid actually in trouble on July 22?

No. ERCOT did not issue an Energy Emergency Alert or a conservation appeal, and reserves stayed above roughly 10,000 MW at the peak. The record was set under normal operating conditions, and the observed peak of 91,308 MW came in slightly below ERCOT's own summer forecast of 92,211 MW. Reliability and 4CP exposure are separate questions.

Are August and September still exposed to new peaks?

Yes. Both August and September are 4CP months, and either can produce an interval higher than July 22 that would replace it in the 2026 4CP set. Historically, some of ERCOT's highest coincident peaks have landed in mid-to-late August. Buyers with 4CP exposure should treat the next eight to nine weeks as the active peak-management window.

For context on how these peak dynamics have shaped the 2026 season so far, see our earlier note on the 2026 4CP window and the peaks remaining after mid-July, and the current Texas commercial electricity rates chart for rate-band context by TDU.