April 14, 2026
This is the third installment in V2G News’ State Profile Series, following Connecticut and California. Each state tells a different story about what it will take to move vehicle-to-grid from pilots to scale. This is not dissimilar to the early days of rooftop solar, where adoption varied widely across states based on regulatory frameworks and market structure. In Texas, the unique structure of the energy market may create the conditions for V2G to scale faster and more broadly than anywhere else in the country.
A Market Built on Energy and Price Signals
To understand Texas, you have to start with the Electric Reliability Council of Texas, or ERCOT. ERCOT manages the flow of electricity to more than 27 million customers, representing about 90 percent of the state’s electric load. In 2023, the system reached an all time peak demand of more than 85 gigawatts, a number that is expected to continue rising as population grows, manufacturing expands, and electrification accelerates.
Unlike most organized wholesale markets in the United States, ERCOT operates as an energy only market, meaning there is no forward capacity construct designed to incentivize investment in new generation resources. In capacity markets, forward payments provide a predictable revenue stream intended to support the development and retention of generation needed to meet future reliability requirements. By contrast, the energy only model relies on wholesale energy prices as the primary signaling mechanism for both new investment and ongoing operations.
In ERCOT, these signals to owners and developers of generation capacity are expressed through prices in the day-ahead and real-time markets, which can fluctuate significantly based on system conditions. While average prices are often modest, periods of system stress can produce sharp price spikes, with real-time prices exceeding $1,000 per megawatt hour during peak conditions. These events occur during a relatively small number of hours, yet they drive a disproportionate share of total system costs and play a central role in shaping long-term investment behavior.
At the same time, Texas has become the national leader in both wind and solar generation, with these resources now playing a central role in meeting rising demand. Since 2023, wind and solar have been the fastest-growing sources of electricity in ERCOT, together supplying more than one-third of total demand in 2025. Utility-scale solar in particular has expanded rapidly, with output in the first nine months of 2025 reaching roughly four times its 2021 level. This growth is increasingly reshaping net load patterns, reducing midday reliance on natural gas and shifting system needs into the evening hours.
Energy storage is beginning to play a critical role in this transition. Battery deployments have accelerated in recent years, with storage systems now regularly charging during periods of high solar output and discharging into the evening peak. By the summer of 2025, batteries were supplying an average of about 4 gigawatts during evening hours, helping to bridge the gap as solar generation declines.
The result is a grid that is becoming more dynamic and more dependent on flexibility. As the generation mix shifts toward variable resources, the ability to respond quickly to changing system conditions becomes increasingly valuable.
Taken together, these dynamics make flexibility not just valuable, but essential. Resources that can respond to price signals in real time, including distributed energy resources and electric vehicles, are uniquely positioned to support reliability, manage costs, and help balance an increasingly dynamic system.
Yet despite these strong underlying signals, residential flexibility remains underdeveloped. Recent analysis by the Brattle Group finds that Texas ranks in the bottom half of U.S. states in residential demand response participation as a share of peak demand, pointing to a large, untapped resource base.
Retail Competition as a Platform for Innovation
Texas is unique not only at the wholesale level but also in how electricity is sold to customers. In much of ERCOT, consumers can choose their Retail Electric Provider, while transmission and distribution utilities continue to operate the wires as regulated monopolies. This structure, established under Texas’s retail choice framework, creates a competitive layer between the wholesale market and the customer that is less developed in most other U.S. markets.
Today, this competitive market includes more than 170 retail providers serving over 8.5 million customer accounts across ERCOT, offering a wide range of plans that vary in pricing structure, contract length, and energy mix. Retail providers are not simply pass through entities. They design products, pricing structures, and bundled offerings that directly shape customer behavior, including exposure to wholesale price signals and integration with distributed technologies.
Competition has led to a wide variety of rate options, including fixed, variable, and time varying plans, as well as targeted offerings designed to reduce energy costs and shift load. Programs such as free overnight EV charging offered through partnerships between GM Energy and Reliant Energy provide bill credits to customers who charge during off peak hours. Similar offerings from Ford Motor Company and TXU Energy reinforce how retail competition is translating wholesale price signals into customer facing programs. These offerings reduce consumer costs while aligning charging behavior with system needs, shifting load away from peak periods and toward times of lower demand and higher renewable generation.
In ERCOT, EVs are not just incremental load. They are becoming flexible, customer sited assets that can respond directly to market signals. In this model, EV charging is no longer just a commodity service. It becomes a managed, value generating resource embedded within competitive retail offerings.
From Retail Programs to Market Participation: ADER and ERCOT’s Proposed Residential DR Program
While retail innovation is advancing rapidly in Texas, the long term value of distributed resources will depend, at least in part, on their ability to participate more directly in wholesale markets or through market structures that create clearer compensation for flexibility. Two developments matter here: ERCOT’s Aggregated Distributed Energy Resource, or ADER, pilot, and ERCOT’s proposed Residential Demand Response program.
Established through a proceeding at the Public Utility Commission of Texas, the ADER pilot is designed to evaluate whether distributed assets such as batteries, flexible loads, and electric vehicle fleets can be aggregated and operated as a single resource capable of responding to ERCOT dispatch instructions. In concept, this creates a framework for virtual power plants to participate alongside traditional generation in energy and ancillary service markets.
For V2G, the opportunity is clear. Electric vehicles, when aggregated, have the potential to meet core participation requirements such as dispatchability, telemetry, and performance verification. In an energy only market like ERCOT, where price spikes during a limited number of hours drive a significant share of system costs, flexible resources that can respond during these periods could, in theory, capture meaningful wholesale market value.
At the same time, ADER remains an early stage effort. Participation in the pilot has been limited, with only a handful of virtual power plants currently active, providing on the order of tens of megawatts of capacity, well below initial targets. Early program design constraints, integration challenges, and market complexity have slowed adoption, and the framework is still evolving as it transitions into ERCOT’s broader stakeholder process.
ERCOT’s proposed Residential Demand Response program is different. Rather than creating a direct wholesale participation pathway, it gives Retail Electric Providers and non-opt-in entities a stronger price signal to develop residential flexibility programs around resources such as smart thermostats, home batteries, and managed EV charging. Under the proposal, participants would be compensated for verified reductions during top seasonal net load hours, with program compensation effectively capped at 500 MW. Brattle’s analysis finds that this design could increase cost-effective customer incentive payments by roughly 2x to 3x, potentially enough to move participation toward levels seen in more mature programs elsewhere and to reach the cap within a few years.
This matters for V2G even though the program does not yet include bidirectional EV exports. In fact, the Brattle study models managed EV charging, not V2G, and explicitly notes that bidirectional capability could provide additional value once technically and commercially viable. What the proposed program does offer is something Texas has lacked: a more explicit mechanism for turning residential flexibility into customer compensation at scale.
It also clarifies the limits of the current approach. The same analysis finds that the proposed program would have only a modest effect on average market prices, on the order of 3 to 4 percent, or less than $2/MWh annually, because the 500 MW cap constrains its market wide impact. That is not a weakness so much as a reminder that the value of flexibility in ERCOT is concentrated in a relatively small number of high value hours. It is precisely the kind of value profile that could make V2G compelling once export pathways and compensation structures mature.
Taken together, ADER and the proposed Residential Demand Response program show that Texas is experimenting on two fronts at once. One is a direct but still immature pathway to wholesale participation. The other is a more immediate retail facing mechanism to expand residential flexibility. Neither is yet a complete answer for V2G, but both are important pieces of the foundation.
Early Signals: Tesla and the Shift from Concept to Deployment
Texas is now beginning to move from concept to early deployment. Tesla has launched its first U.S. vehicle-to-grid offering through its PowerShare Grid Support program, starting with Cybertruck owners in select Texas markets.
This development builds on the foundation of managed charging, which has already demonstrated how electric vehicles can function as flexible demand by shifting load to periods of lower prices and higher renewable output. Bidirectional capability extends that model. Instead of simply adjusting when energy is consumed, EVs can now export energy back to the grid, responding directly to the price spikes that define ERCOT’s economics. In an energy only market, where value is concentrated in a relatively small number of high price hours, a resource does not need to operate continuously to be valuable. It simply needs to be available at the right time, a profile that aligns closely with how vehicles are used.
What makes Tesla’s approach possible today is Texas’s retail market structure. As a licensed Retail Electric Provider, Tesla can aggregate customer load and generation behind the meter and optimize it against wholesale prices, then translate that value into customer bill credits. This allows Tesla to compensate Cybertruck owners for exports without relying on a formal wholesale participation pathway such as ADER. Instead, value is created through retail supply optimization and event-based dispatch, effectively bridging wholesale price signals and customer compensation within the existing market framework.
Recent analysis of ERCOT’s proposed Residential Demand Response program reinforces this point. Even well designed demand response programs are expected to have only a modest effect on average prices across the system. The real value lies not in broad price suppression, but in targeted performance during a relatively small number of high value hours.
With each Cybertruck equipped with a 123 kWh battery, even a relatively small number of participating vehicles represents a meaningful source of distributed capacity. Tesla’s decision to launch in Texas is not accidental. The combination of strong price signals and retail market flexibility creates a pathway to begin monetizing bidirectional capability today, even as formal market structures continue to evolve.
Still, these deployments remain early. They are important signals of direction, not yet indicators of scale.
Conclusion: A Market Test for V2G
Texas is not approaching V2G through mandates or a predefined policy framework. Instead, it is testing whether distributed flexibility can emerge and scale within a market driven system. The pieces are beginning to take shape. Strong price signals reward responsiveness. Retail competition enables rapid innovation and customer facing offerings. ERCOT’s proposed Residential Demand Response program suggests the market is beginning to create a more explicit pathway for residential flexibility. Early deployments, including vehicle based programs, are starting to demonstrate how value can be created and shared.
What happens next will determine whether V2G in Texas moves beyond early signals to meaningful scale. Progress will depend on aligning retail innovation with wholesale market participation, clarifying interconnection pathways for bidirectional systems, and, critically, establishing compensation structures that are durable enough to support investment. If these elements come together, Texas could become the first state where V2G scales because it makes economic sense, not because it is required. And if that happens, it will offer a compelling model for the rest of the country, one where EVs are not just part of the grid, but active participants in shaping its future.
