Rates Skew Higher: Aug 2026 | Texas Commercial Plans

Market Pulse: Texas Commercial Electricity Rates, August 2026

Texas commercial electricity rates in August 2026 moved higher where it actually counts, even though the blended average across the tracked pool printed lower. Across the 1,000 active commercial plans in the texascommercialplans.com database this week (August 11 through August 17, 2026), 22 plans repriced: 16 moved higher and only 6 moved lower. Every one of the five TDU delivery zones tracked here posted a flat or higher average, across 29 tracked Texas REPs.

The pool-wide average did come in about 4.3% lower, but that figure is a composition artifact rather than a price move. A full catalog re-index this week changed which plans sit in the sample, and when the mix changes, a blended average shifts for reasons that have nothing to do with what providers are quoting. Measured the defensible way, comparing only plans present in both weeks, the direction is up. For commercial buyers, the operative signal is that ERCOT summer load and delivery-side cost pressure are still pushing offers higher, not lower.

What's Moving the Market

Oncor implemented a temporary surcharge on August 1, 2026. The adjustment follows the completed base rate review and the gap between prior rates and the PUCT-approved rates effective June 1, 2026. Because Texas REPs pass TDSP delivery charges straight through to business invoices, your all-in cost per kWh can rise even when the energy charge on your contract never changes. Read your next invoice by line item, not by the headline rate. Details in Oncor's second quarter results.
ERCOT cleared record summer demand with roughly 3.7 GW less backup power than its own model called for. Officials indicated they will not make up the shortfall in 2026, but a stricter reserve standard is under review for 2027, per reporting on the Dallas Morning News analysis. A tighter reserve margin requirement generally raises the cost of serving load, and that cost eventually reaches commercial contracts. If you are pricing a term that extends into 2027, treat this as a modest upward bias rather than a settled number.
Data center interconnection remains stalled, keeping future load uncertain. ERCOT requested a good cause exemption after missing Batch Zero approval deadlines, leaving already-evaluated projects facing months of delay. The state audit directive covering the Batch Zero study process adds another layer. For buyers, this is a two-sided risk: delayed load is near-term relief, but the queue itself signals sustained demand growth behind it.
Record peak demand and AI-driven load growth stayed at the center of weekly market commentary. Mid-August market reporting flagged a record ERCOT peak alongside the interconnection backlog. The recurring recommendation to commercial users has been to review contract expirations early and evaluate fixed or block structures rather than riding index exposure through peak season.
Advertised commercial offers remain widely dispersed across the market. Public rate comparison sources this week showed fixed offers spanning single digits to well past 13 cents per kWh in the same geography. That spread is not noise. It reflects load profile assumptions, contract term, usage floors, and location-based delivery charges, which is precisely why a quoted headline rate tells you very little until it is normalized against your own consumption pattern.

Pricing Trend Analysis

The cleanest read on the week comes from the matched set: the 64 plans that carried a reliable week-over-week comparison through the catalog refresh. Within that set, 22 plans repriced and 42 held steady. The repricing skewed decisively upward, with increases outnumbering decreases by better than two to one.

Direction by delivery territory was close to uniform. Four of the five TDU zones posted higher average pricing week over week, and Oncor territory was effectively flat, edging fractionally lower. That uniformity matters more than any single zone's magnitude: when every territory moves the same way at once, the driver is usually systemic (wholesale forward curves, delivery cost adjustments, peak season risk premium) rather than one provider repositioning.

Segment structure is where the more useful signal sits. Short-term contracts in the 1 to 12 month band carried the highest average pricing of the three segments this week, while the 13 to 24 month band was the cheapest on average and the 25 to 36 month band sat between them. That ordering is the inverse of what buyers often assume. Flexibility is not free right now: you are paying a visible premium to stay short through peak season, and the middle of the term curve is where the market is currently most competitive.

A handful of tracked plans posted double-digit percentage repricing in both directions, which is why a single average understates what is actually happening at the offer level. Our rate trend chart shows the short-term and mid-term segment lines diverging over recent weeks rather than converging, with the short-term premium widening as summer peak risk gets priced in.

See full pricing breakdown in our data download, and compare against last week's report and the August 4 edition for the running trend.

REP Spotlight: NRG

This week's spotlight is NRG, one of the largest retail electricity providers operating in the Texas commercial market. Within our tracked commercial dataset, NRG carries one of the broadest product footprints of any provider we follow.

Coverage is statewide across all five TDU territories: Oncor, CenterPoint, AEP Central, AEP North, and TNMP. That full-footprint presence is relatively uncommon and makes NRG a practical benchmark quote for multi-site operators who want consistent contract terms across geographically split locations.

The term ladder is unusually deep, running from 3 months at the short end out to 60 months. That range covers both bridge contracts for buyers waiting out a pricing cycle and long-dated fixed commitments for organizations prioritizing budget certainty over optionality. Products in the tracked commercial set are fixed-rate structures, and we do not currently track green or renewable-designated commercial products from this provider, so buyers with a renewable procurement mandate will likely need to look elsewhere or request a bespoke structure.

On positioning, NRG's tracked commercial offers sit below the market average in our dataset. Directionally, that places them in the competitive tier rather than the premium tier, though as always the advertised rate is only meaningful once delivery charges and your specific load profile are layered in.

Get this REP's full plan data in our data download.

Buyer Intelligence

The practical takeaway this week is to stop reading blended market averages as if they were price signals. Averages move when the plan mix moves, and this week is a clean example: the pool average fell while actual repricing ran higher by more than two to one. If your procurement process triggers off a published average, you would have drawn exactly the wrong conclusion. Anchor decisions to the matched-plan direction and to your own territory instead.

Second, the delivery side deserves attention it rarely gets. With the Oncor surcharge active as of August 1 and a stricter 2027 reserve standard under review, a meaningful share of your all-in cost is moving independently of whatever energy rate you sign. When you compare offers, normalize to a delivered cost per kWh at your actual usage level. A contract that looks two or three percent cheaper on the energy charge can easily lose that advantage once pass-through components are applied.

Are Texas commercial electricity rates going up or down in August 2026?

They are trending up. Among the 64 tracked commercial plans with a clean week-over-week comparison this week, 22 repriced and 16 of those moved higher, against just 6 that moved lower. Four of five TDU zones posted higher averages and the fifth was essentially flat, so the upward bias is broad rather than isolated to one territory or provider.

Should commercial buyers lock in rates now or wait?

Buyers with contracts expiring in the next 60 to 90 days should be actively soliciting quotes now rather than waiting for a pullback. Repricing has skewed higher, peak season risk is still being priced in, and both the ERCOT reserve standard review and the Oncor delivery surcharge point toward upward pressure into 2027. If you need flexibility, note that short-term contracts currently carry the highest average pricing of any segment, so a mid-length term may cost less than a bridge.

Data Snapshot

Tracked REPs this week: 29
Active commercial plans: 1,000
Plans with a clean week-over-week match: 64
Plans with rate changes: 22 (16 higher, 6 lower)
Plans removed this week: 2
TDU territories covered: 5 (Oncor, CenterPoint, AEP Central, AEP North, TNMP)
Average contract term: 22.3 months
Catalog note: the full plan catalog was re-indexed this week, so raw plan-addition counts reflect a data refresh rather than genuine new market entry. Rate-change and removal figures above are churn-filtered.

Full rate data, plan comparisons, and historical trends available in our data download. You can also browse tracked commercial plans or review our daily market news coverage between weekly editions.

Frequently Asked Questions

Which TDU territory had the most rate movement this week?

AEP North showed the largest week-over-week average swing of the five tracked territories, followed by TNMP and CenterPoint, all of them higher. Oncor was the outlier at essentially flat. The AEP North figure should be read with caution, since a thinner matched-plan sample in that territory makes its average more sensitive to composition changes than the larger Oncor and AEP Central pools.

How do Oncor's delivery charges affect Texas commercial electricity bills?

Oncor's temporary surcharge took effect August 1, 2026, and flows through to commercial invoices as a pass-through TDSP delivery charge. Texas REPs bill these charges separately from the energy rate you contracted, which means your total cost per kWh can increase mid-contract even on a fixed-rate plan. Always compare offers on a delivered basis at your actual usage level.

What contract length offers the best value for Texas commercial buyers right now?

The 13 to 24 month band carried the lowest average pricing of the three tracked segments this week, below both short-term and 25 to 36 month contracts. Short-term contracts of 1 to 12 months were the most expensive on average, meaning buyers are paying a premium for flexibility through peak season. Mid-length terms currently offer the better balance of price and commitment.