Key Texas Energy Trends to Watch in 2026

Summer is here, and if your business is exposed to energy market risk, or your contract is coming up for renewal — you may be paying closer attention to energy prices than usual. But summer shouldn't be the only time you think about your energy strategy.

The ERCOT market continues to evolve, and the decisions businesses make today can have long-term cost implications. From changing weather patterns and rapid demand growth to new regulations and grid updates, several factors are shaping the Texas energy market in 2026 — and beyond. Understanding what's driving the market can help you make more informed purchasing decisions and better manage risk.

Weather continues to have the greatest immediate impact on ERCOT prices.

Going into summer, forecasts pointed to the potential for a strong — or even super — El Niño by late summer or early fall. These conditions typically bring warmer weather to the West and South. As of mid-July, we have officially moved into a moderate El Niño, while daily sea surface temperature (SST) values suggest we have pushed into strong El Niño territory. Although the South has experienced relatively benign weather so far this summer, recent trends suggest that the risk for a hotter August is in play.

High temperatures drive electricity demand higher, and when that demand coincides with low wind generation, prices can rise quickly and become highly volatile.

While weather mainly affects short-term prices, major weather events and longer-term climate patterns also influence forward pricing. Events such as Winter Storm Uri in 2021 and the extreme ERCOT heat event in 2023 exposed reliability risks that continue to be reflected in future market prices.

Texas is experiencing unprecedented electricity demand growth, fueled by AI data centers, industrial expansion, electrification, cryptocurrency mining, and continued population growth.

ERCOT's load forecasts continue to increase, and large-load interconnection requests remain a major focus for regulators and market participants. As demand projections rise, uncertainty grows around whether future generation will be able to keep pace, and what that could mean for long-term electricity prices.

Additionally, how policymakers address this rapid demand growth will also influence market risk and whether pricing trends become more bullish or bearish over time.

Alongside market growth, ERCOT's regulatory environment continues to evolve.

State leaders and regulators are actively developing and implementing changes related to generation development, large-load interconnections, reliability standards, transmission planning, and cost allocation. Some recent policy changes have already affected market costs, while several additional proposals are still moving through the implementation process.

Approved in 2025, Senate Bill 6 is now moving through implementation. This legislation introduces several changes related to large electricity users, including:

• Large-load forecasting rules to improve planning and forecasting
• Net metering rules for large loads co-located with generation resources
• New standards governing large-load interconnections, including study agreements, fees, refunds, and cost responsibilities
• A reliability service designed to competitively procure demand reductions from large loads
• An evaluation of transmission cost recovery (TCOS), including whether the current wholesale transmission methodology based on four coincidental 15-minute peaks (4CP) should shift to 12 coincidental 30-minute peaks. Regulators are also evaluating how retail transmission costs will be allocated for large-load customers, including system upgrade costs, minimum demand charges, and annual updates to cost allocation factors.

The outcome of these discussions could significantly affect transmission costs, making operational discipline increasingly important for businesses looking to manage future expenses.

As large-load policies continue to evolve, ERCOT is also refining the assumptions that will be used in the first Reliability Standard Assessment under Texas' new reliability framework.

One of the biggest unknowns is how much demand will ultimately materialize from data center growth. The results of this assessment could influence future resource adequacy policies and encourage additional regulatory action.

Where new generation connects—and where large energy users choose to locate—will increasingly influence transmission costs and congestion.

If transmission cost recovery (TCOS) shifts away from the current 4CP methodology, managing how much and when your facilities consume electricity may become an even more important strategy for controlling overall energy costs.

Texas' generation mix continues to change as more solar resources and battery storage come online.

ERCOT has also implemented a new real-time market design known as Real-Time Co-Optimization Plus Battery (RTC+B). This framework allows energy and ancillary services to be dispatched more efficiently while improving how battery storage resources are modeled and utilized.

As peak (scarcity) pricing shifts away from broad system-wide impacts and more toward real-time ancillary service pricing, businesses with exposure to market-based cost components (like ancillaries) should carefully evaluate their exposure ahead of periods of high demand.

With so many variables influencing the ERCOT market, flexibility has become increasingly valuable.

Locking in a fixed price for an extended period may provide certainty, but it can also limit your ability to respond to changing market conditions, reduce costs, or take advantage of new opportunities as they arise.

That's why many businesses are considering a managed energy purchasing approach.

A managed approach can provide:

• Customized risk management based on your organization's goals
• Flexibility to make purchasing decisions as market conditions change
• Opportunities to incorporate cost-reduction strategies, such as load management or curtailment
• A longer-term approach to risk management instead of restarting the process every time a contract expires

Rather than locking in your entire energy requirement at once, a managed approach combines layered forward purchases over time with strategic participation in the index market. This allows businesses to lock in favorable pricing when opportunities arise, while still maintaining flexibility to respond to changing market fundamentals.

Additionally, a managed approach also helps reduce renewal risk. Instead of reaching the end of a fixed contract only to discover that market prices have risen significantly, businesses can build their positions gradually over time, making purchasing decisions based on market conditions rather than contract expiration dates.

For organizations pursuing additional savings through load management, a managed strategy also offers greater flexibility. Some purchasing structures limit the financial benefits of reducing demand during peak periods, while a managed approach is designed to support efforts like coincidental peak management or voluntary curtailment when market conditions make those strategies valuable.

Managing energy procurement has become more complex, but businesses don't have to do it on their own.

Working with an energy strategist and a Strategic Client Services team can help you stay informed about market developments, understand how changing fundamentals may affect your costs, and make purchasing decisions with greater confidence as conditions evolve.