An electric vehicle parked after the evening commute usually remains stationary until the following morning. The moment it is plugged in, however, the car changes from a machine that merely consumes electricity into an energy resource capable of storing power and returning it when needed. The next phase of competition in the EV market will move beyond batteries that provide longer driving ranges. It will revolve around when electricity is purchased, how it is stored, and to whom it can be resold. A new energy market is opening in parking lots as vehicles on the road become connected to the urban power grid.

For an EV driver, the most unsettling moment comes when the battery gauge is falling quickly and there is no charging station in sight. During the early phase of EV adoption, eliminating this so-called “charging anxiety” was the most urgent task. Governments, automakers, and charging operators concentrated on installing more chargers in more convenient locations. Their reasoning was that people would feel comfortable choosing an EV only when charging became as fast and convenient as refueling.

According to the International Energy Agency’s Global EV Outlook 2025, approximately 1.3 million public charging points were installed worldwide in 2024. The global total surpassed five million. Around 150 million additional charging points are projected to be installed between 2025 and 2030. Roughly two-thirds of them are expected to be home chargers, while about 30 percent will be installed at workplaces, commercial properties, and other private facilities. Public chargers are projected to account for approximately 8 percent.

For drivers, 150 million charging points are welcome news. For the power grid, they carry a somewhat different meaning. They represent an enormous number of new electricity-consuming devices connecting to the system. A problem arises when people return home at similar times and begin charging their vehicles simultaneously. Evenings already bring high electricity demand as lighting, heating or cooling, and cooking appliances operate at the same time. If hundreds of thousands of EVs begin drawing power simultaneously, the existing evening peak could become significantly higher and steeper.

The scale of this change becomes clearer when the focus narrows to an underground apartment parking garage. At first, installing only a few chargers may be sufficient. Once the number of EVs rises to 10, 50, or 100, however, it becomes difficult to charge every vehicle at maximum speed simultaneously. Supplying more electricity may require upgrades to transformers and distribution equipment, increasing both construction and maintenance costs. In some cases, the infrastructure needed to deliver electricity requires more money and time than the chargers themselves.

Yet not every vehicle parked overnight needs to begin charging at full speed the instant it is plugged in. If a vehicle arrives at 7 p.m. and leaves at 7 a.m. the next day, it remains parked for 12 hours. If it needs only four hours to charge, the remaining eight hours offer room for adjustment. Because vehicles have different departure times and energy requirements, charging them in an appropriate sequence can serve more cars without excessive expansion of electrical infrastructure.

This is why the central challenge of EV charging is shifting from “Where should chargers be installed?” to “When and at what speed should charging take place?” If the number of chargers opened the first chapter of the EV market, technology that manages charging times is opening the next.

Smart charging is a technology that automatically adjusts charging times and speeds by allowing vehicles, chargers, and the power grid to exchange information. Even when a driver plugs in at 7 p.m., charging does not need to begin immediately. The vehicle can start charging later at night, when electricity demand and prices fall, and receive the power it needs before the driver departs the following morning.

If conventional charging resembles turning on a tap to fill a container, smart charging resembles a system that automatically controls the valve after considering the price of water, current usage, and the time available. The driver enters the departure time and desired battery level. The vehicle reports its current battery status, while the utility provides information about time-based rates and grid conditions. The charging management system then determines the most appropriate sequence and speed after considering the needs of multiple vehicles.

EVs do not need to become sacrificial participants that endure inconvenience for the sake of the power grid. As long as the necessary battery level is available in the morning, most drivers have little reason to care whether charging occurs at 9 p.m. or 2 a.m. They may even reduce charging costs by using cheaper off-peak electricity. Utilities can avoid periods of concentrated demand, while charging operators can manage more vehicles using the same electrical infrastructure.

The purpose of smart charging is not simply to reduce the total amount of electricity consumed. Vehicles still need the power required for transportation. What matters is moving the same amount of electricity consumption to a time when the grid can accommodate it more easily. Smart charging does not eliminate demand; it changes the timing of that demand.

This modest shift in time creates much greater value when combined with renewable energy. In regions with abundant solar power, electricity is plentiful during sunny daytime hours, but generation drops rapidly after sunset. If EVs parked at offices or shopping centers absorb solar power during the day, less surplus electricity needs to be curtailed or wasted. At night, home chargers can store electricity when wind generation increases. Vehicle batteries become buffers that absorb the variable output of renewable energy.

The fact that a technology is available, however, does not automatically change driver behavior. It is difficult to secure participation simply by asking people to delay charging for the benefit of the grid. Tangible benefits, such as time-of-use discounts or compensation for automated charging, are necessary. The system must also be simple to use. Drivers should not have to study complex electricity prices every day. They should be able to plug in, enter a departure time, and allow the most economical charging plan to run automatically.

Consumers do not want to become electricity-market experts. They want a service that ensures a sufficient battery level in the morning, lowers their charging bill, and allows them to change their settings whenever necessary. The success of smart charging depends as much on this ordinary convenience as it does on sophisticated algorithms.

While smart charging controls when electricity enters a vehicle, bidirectional charging reverses the direction of the flow. With conventional charging, electricity travels only from the grid to the vehicle battery. With bidirectional charging, electricity stored in the vehicle can be sent back to a home, a building, or the power grid. The automobile becomes both a consumer and a supplier of electricity.

The terminology changes depending on where that electricity is sent. When a vehicle supplies electricity to camping equipment or electronic devices, it is called vehicle-to-load, or V2L. Supplying a home is known as vehicle-to-home, or V2H; connecting to a building is vehicle-to-building, or V2B; and sending electricity to the public power grid is vehicle-to-grid, or V2G. Although the applications differ, they share the same principle: using a vehicle battery for purposes beyond driving.

EVs contain larger batteries than many people realize. A battery with a capacity of 60 kilowatt-hours can be several times larger than a typical residential storage system. During a power outage, it can supply essential equipment such as refrigerators, lights, and communication devices for a considerable period. Under normal conditions, the vehicle can charge when electricity is inexpensive and supply its stored power to the home when rates are high. A car parked in the garage thus becomes both an emergency generator and a residential battery.

V2G goes one step further. It links thousands of EVs and allows them to participate in the electricity market as a single virtual power plant. One vehicle cannot provide a large amount of electricity, but the situation changes when many vehicles are aggregated. If electricity demand rises suddenly or solar and wind generation falls below expectations, connected vehicles can supply power for a short period and help maintain the balance of the grid.

What makes this model particularly interesting is that automobiles do not need to generate electricity continuously like conventional power plants. The power system must keep supply and demand almost perfectly balanced in real time, so resources capable of correcting short-lived imbalances also possess market value. If large numbers of vehicles reduce charging or release small amounts of electricity at the necessary moment, they can create an effect similar to that of a large power plant changing its output.

In Utrecht, the Netherlands, a project was launched in 2025 to introduce 500 bidirectional-charging Renault EVs into a car-sharing service. Residents use the vehicles for transportation, while parked cars connect to the local power grid. On the road, the automobile functions as shared mobility; in the parking lot, it works as an energy-storage asset. By improving both vehicle utilization and battery utilization, the project points toward a new direction for the EV business.

China is also expanding V2G standardization and demonstration projects. The International Energy Agency reports that China is pursuing policies aimed at securing 10 gigawatts of flexible capacity through V2G and related technologies by 2030. This signals that EV policy is moving beyond vehicle sales and charger numbers toward integration with the power grid.

A new source of income could also open for drivers. Cars spend a large portion of each day parked. Until now, a stationary vehicle has created little economic value. Once connected to the electricity market, however, its idle time can become an asset. Charging when electricity is abundant and inexpensive and selling part of that power during periods of high demand can reduce charging costs or generate additional compensation. Vehicle owners shift from consumers who only pay for fuel or electricity to suppliers participating in energy transactions.

When people hear that they may be able to sell electricity from their cars, concern can arise before excitement. They may ask, “Will someone else be able to use my battery without my control?” “Will repeatedly sending electricity out of the vehicle wear the battery down more quickly?” or “What happens if I need to drive a long distance tomorrow and the battery is depleted?” Unless these concerns are addressed, V2G may remain confined to interesting demonstration projects.

Batteries gradually lose performance as they go through charging and discharging cycles. The extent to which bidirectional charging shortens battery life, however, depends on the depth and frequency of discharge, temperature, charging speed, and battery-management strategy. Fully draining a battery on every occasion does not have the same effect as exchanging small amounts of electricity within a limited range. If the system considers driving plans and battery condition and operates within a safe range, the burden can be reduced.

More important than technical management are clear standards for responsibility and compensation. It must be evident whether an automaker’s battery warranty remains valid when the vehicle participates in V2G. It is also necessary to determine whether drivers receive sufficient compensation for allowing the grid to use their batteries. A market is unlikely to grow if drivers are asked to accept uncertainty about an expensive battery merely to earn a small amount from electricity sales.

The vehicle owner’s right to use the car must always take priority. If a driver plans a long trip beginning at 7 a.m., the system must preserve the electricity needed for that journey. Users should be able to set a minimum battery level, departure time, and whether they wish to participate in V2G. They must also have the right to begin charging immediately or stop supplying electricity when an unexpected schedule change occurs.

Technical standards present another obstacle. Vehicles, chargers, building energy-management systems, utilities, and electricity-market platforms must communicate in the same language. Matching plug specifications is not enough. The systems must safely transmit information about battery condition, exchange charging and discharging commands, and accurately meter the amount of electricity traded. Expansion will remain slow if every automaker uses a different system and every region applies different rules.

Settlement methods also matter. Policymakers and market operators must decide whether drivers should be paid only for the amount of electricity they send to the grid or also for keeping their vehicles connected and available when power may be needed. In regions with low electricity prices, simple electricity sales may not generate sufficient revenue. Commercial viability improves when EVs can participate in a wider range of grid services, including peak-demand reduction, frequency regulation, and emergency reserves.

Privacy and cybersecurity issues follow closely behind. Charging data can reveal a vehicle’s location, usage times, travel habits, and battery condition. The information may be sensitive enough to indicate when someone regularly leaves home. If large numbers of chargers are hacked and activated or shut down at the same time, they could also disrupt the power grid. A charger is becoming both a parking amenity and a digitally connected piece of electrical infrastructure.

The expansion of V2G will not be determined by battery performance alone. The rules jointly designed by automakers, charging operators, utilities, market operators, insurers, and regulators will be even more important. Technology is moving toward the point where electricity can be drawn from vehicles. The remaining task is to agree on whose battery may be used, under what conditions, and how the risks and rewards should be shared.

In the competition surrounding EV charging, the promise of “faster” carries enormous appeal. For drivers accustomed to filling a fuel tank, even a 30-minute charging session can feel lengthy. Ultra-fast charging is essential at highway rest areas and along long-distance travel routes. Shorter charging times reduce driver inconvenience and allow stations to serve more vehicles.

The fastest possible charging is not necessary everywhere, however. The situation is different in apartment parking garages, where vehicles remain overnight, and workplace parking lots, where they may remain throughout the day. Installing expensive infrastructure and reserving enormous amounts of power to charge a vehicle in 20 minutes makes little sense when it will remain parked for 10 hours. Fast charging matters while travelling; intelligent charging matters where vehicles stay for extended periods.

The grid also experiences a different burden depending on charging speed. If several vehicles begin ultra-fast charging simultaneously, they create a large surge in electricity demand. Even when a charging station has a low average utilization rate, its transformers and distribution equipment must be prepared for maximum demand. When a grid connection is delayed, installed chargers may be unable to operate at their intended output.

This is why large fast-charging stations may be equipped with battery-storage systems. The station charges the storage system when electricity demand is low and draws from it when many vehicles arrive, reducing the amount of electricity pulled from the grid all at once. When solar generation is added, the charging station changes from a facility that only consumes electricity into a local energy hub that produces, stores, and supplies it.

The basis of competition among charging operators is also changing. Until now, securing attractive locations and increasing the number of chargers have been essential strategies. In the future, success will increasingly depend on predicting electricity prices, coordinating the charging schedules of multiple vehicles, and integrating storage systems with renewable energy. The charging business is expanding from an equipment business focused on installing chargers into an energy-management service powered by data.

Automakers are also moving beyond a model in which their relationship with customers ends after the vehicle is sold. Through vehicle batteries and charging software, they can provide services that reduce electricity bills, offer emergency power, and enable participation in electricity markets. Utilities are becoming platform operators that connect not only power plants and transmission lines but also batteries in customers’ garages. The boundaries between once-separate industries are collapsing through a single charging cable.

South Korea possesses both favorable and difficult conditions for smart charging and V2G. The high proportion of apartment residents makes it difficult for individuals to install chargers freely, and disputes may arise over parking spaces and available electrical capacity. At the same time, dozens or hundreds of vehicles gather in one location and remain parked for long periods, creating a favorable environment for integrated charging management.

If every vehicle begins charging immediately after its owner returns home, an apartment complex’s peak electricity demand can rise rapidly. If charging is sequenced according to each vehicle’s departure time and required energy level, the existing electrical infrastructure can be used much more efficiently. Software can coordinate the charging order instead of requiring transformer upgrades whenever the number of EVs increases. The performance of the management system becomes as important as the number of chargers.

In 2025, the South Korean government expanded its budget for EV charging infrastructure to approximately 620 billion won. A considerable portion of this funding was allocated to fast-charging infrastructure, while smart-charging functions became increasingly important in the slower-charging segment. As the EV market moves into a stage of mass adoption, evaluation must move beyond counting installed chargers. Actual utilization, failure rates, grid-connectivity capabilities, and the effect of managing peak-time demand must also be considered.

The initial V2G market is more likely to emerge among vehicles with predictable schedules than among individually owned passenger cars. City buses, school buses, delivery vehicles, rental cars, and corporate fleets have relatively predictable operating times and parking locations. Because a single operator manages multiple vehicles, contracts and settlement are easier to organize. Electric buses and logistics vehicles that return to depots at night or at designated times could become large, distributed energy-storage resources.

Corporate EVs can also assume a new role. During the day, they support employee transportation; while parked, they can help reduce a building’s energy costs. Businesses can charge vehicles when electricity is inexpensive and use their batteries to support the building during periods of peak demand. A workplace equipped with solar panels can store electricity generated during the day in company vehicles and use it at another time.

For this market to grow, the benefits received by vehicle owners must be clear. Drivers need confidence that sufficient battery capacity will be available when they depart, that their warranties will remain valid, and that they will be compensated fairly for participating. They should be able to join with a few taps and withdraw whenever they choose, without having to learn complex electricity-market terminology. A system in which platforms capture the benefits while drivers bear the inconvenience and risk will not endure.

Integrating EV charging into the electricity market is drawing a new industrial map. Automakers provide energy services, charging operators manage electricity demand, and utilities connect to batteries on the road. Building managers begin to view parking lots not simply as places to store vehicles but as locations where energy can be stored and traded.

Whether EVs become a burden on the power grid or a resource that supports it will not be determined by the number of vehicles alone. The direction will depend on how precisely charging times can be distributed and how fairly the value stored in vehicle batteries can be traded. Tonight, cars parked in garages quietly wait for the next day’s journeys. The moment those vehicles are connected through a single network, however, the city gains an enormous mobile power plant that it has never possessed before.

International Energy Agency, May 2025, Global EV Outlook 2025: Expanding Sales in Diverse Markets

International Energy Agency, May 2025, Electric Vehicle Charging, Global EV Outlook 2025

European Commission, March 2025, Industrial Action Plan for the European Automotive Sector

Ravi Raj Shrestha et al., August 2025, Smart Charging Impact Analysis Using Clustering Methods and Real-World Distribution Feeders

Reuters, June 2025, Dutch Car Sharing Firm Adds Renault EVs Capable of Powering Local Grid