V2G Solar Design: Bidirectional Charging Guide

Last updated: November 2026

An electric vehicle parked in a driveway can hold more usable energy than most residential battery systems. A 65 kWh EV pack is about five times the size of an assumed 13 kWh home battery. With vehicle-to-grid (V2G) technology, that energy can power the house or export to the grid at peak times. For installers, this changes the design brief: V2G needs bidirectional inverters, a different array-sizing calculation, smart metering and a utility interconnection agreement that standard grid-tied PV never requires. All of that has to land in your solar proposal software before the homeowner sees the quote. This guide walks through each part, from charger architecture to revenue modeling. Related reading: US residential solar market trends.

What this guide covers:

• How bidirectional charging works, AC vs. DC architectures
• The difference between V2G, V2H, and V2L, and why it matters for design
• How V2G changes inverter selection, array sizing, and grid connection
• Which EVs and chargers support V2G in 2026
• The financial case for V2G-ready solar installations
• Regulatory and interconnection requirements by region
• How solar design software must evolve for bidirectional systems

What V2G Actually Means for Solar Installers

The conventional solar-plus-battery design has one job: generate electricity, store what the household cannot use immediately, and draw from storage when the sun is not shining. Energy flows in one direction. A V2G-capable solar system treats the EV battery as a dispatchable asset that can absorb generation, hold it, and release it on demand to the home or the grid.

The EV battery has properties no stationary battery does. It is mobile, so its availability depends on driving schedules. Its state of charge on arrival home varies with daily distance driven. And unlike a home battery that sits at a fixed location and is always connected, the EV is a moving target for energy dispatch logic.

Three new design variables emerge immediately:

Variable storage availability. The EV is not always home. A commuter car can be away from home for most of the working day. Any energy management logic that depends on the EV must account for periods when the storage asset is simply absent.

Dynamic state of charge on arrival. A home battery begins each day at a predictable charge level. An EV does not. If the car returns home with 15% state of charge after a long day, there is no usable V2G capacity until solar or grid power recharges it above the V2G threshold, set by the vehicle maker and charger settings, so check the specific model.

Utility coordination. In V2G, the vehicle discharges to the grid, making it a generator in the eyes of the utility. That requires an interconnection agreement, a certified bidirectional inverter, and in many cases a separate smart meter to measure exported energy. Standard solar G98/G99 notifications in the UK or NEM interconnection in the US do not automatically cover V2G. Our guide to battery solar system design in the UK covers the UK notification process in more detail.

The practical implication is that V2G solar design requires a system-level approach that standard PV design checklists were not built to handle. Getting it right means rethinking inverter selection, array sizing, metering, and the client conversation around what V2G actually delivers.

The opportunity is real. Take an assumed 65 kWh EV pack against an assumed 13 kWh home battery: about five times the energy. If a homeowner drives 40 km per day and consumes 7 kWh in the process, the remaining 58 kWh is potential V2G capacity, subject to vehicle manufacturer limits on discharge depth. Even using half of that (29 kWh) as dispatchable storage changes the economic case for solar dramatically. The system shifts from offsetting imports to actively generating grid revenue during peak hours.

Bidirectional Charging Architecture: AC vs. DC

A standard EV charger is a managed switch. Alternating current from the grid passes through the EVSE (electric vehicle supply equipment), converts to direct current inside the vehicle’s onboard charger (OBC), and flows into the battery. Power moves in one direction only: from wall to car.

Bidirectional charging reverses that flow. DC from the EV battery converts to AC and flows back to the home or grid. The design question is where that conversion happens.

AC Bidirectional Charging

In AC bidirectional systems, power conversion, both AC-to-DC when charging and DC-to-AC when discharging, happens inside the vehicle using the onboard charger. The external EVSE hardware is simpler and less expensive because all the power electronics live in the car.

The limitation is the OBC’s power rating. The OBC’s power rating puts a ceiling on the discharge rate: a V2H or V2G system using AC bidirectional charging cannot push more than the OBC’s rated output, regardless of battery size. As an example, a 65 kWh battery discharging at an assumed 7.4 kW takes roughly 8.8 hours to empty. That suits overnight dispatch but limits rapid grid response events.

AC bidirectional is simpler to retrofit and usually cheaper to build, because the power electronics already sit in the car. Check each vehicle’s documentation for its supported mode.

DC Bidirectional Charging

In DC bidirectional systems, the power conversion happens in the external charger, not the vehicle. The charger handles both AC-to-DC (charging) and DC-to-AC (discharging) with dedicated power electronics. The vehicle’s OBC is bypassed entirely during DC charging and discharging.

The power rate is then set by the external charger rather than the vehicle’s OBC, which can allow higher discharge rates. The trade-off is cost and complexity, because the charger carries the full power electronics. The vehicle must also support DC bidirectional operation through ISO 15118-20, which is still being rolled out across model lines. Compare charger datasheets for rated power and supported vehicles.

DC-Coupled vs. AC-Coupled with Solar

When combining V2G with a solar system, the coupling architecture determines efficiency and complexity.

In a DC-coupled system, solar panels, battery or V2G charger, and inverter all share the same DC bus. Power flows from panels directly to the DC bus, and the inverter handles AC conversion. The EV charges and discharges via the DC bus, avoiding an AC-to-DC-to-AC conversion cycle. Round-trip efficiency is generally higher in DC-coupled systems because there are fewer conversion stages. Our guide to DC bus voltage optimization covers the bus design.

In an AC-coupled system, the solar inverter converts panel output to AC and puts it on the home’s AC bus. The bidirectional EV charger also sits on the AC bus. When charging the EV from solar, the power goes DC (panels) → AC (inverter) → DC (charger). Each extra stage adds losses. This is the lossier option, but it works with any existing solar installation and any AC bidirectional charger.

For new installations, DC-coupled is the better design choice. For retrofits where an existing solar system is already in place, AC-coupled is often the only practical option.

ISO 15118: The Protocol That Makes V2G Work

ISO 15118 defines how the EV and charger communicate. It covers authentication, power scheduling, and in the -20 variant, DC bidirectional power flow parameters. The EV reports its current state of charge, maximum charge and discharge power, and available energy to the charger. The charger, and the connected home energy management system, uses this data to schedule charging and discharging.

Without ISO 15118, a bidirectional charger cannot know how much energy the EV can safely discharge. That is why vehicle-charger compatibility depends on both the connector type (CCS2 or CHAdeMO) and software protocol support, not just the hardware plug.

V2G, V2H, and V2L: Design Implications for Each Mode

The terms V2G, V2H, and V2L are often used interchangeably in marketing materials. They describe three distinct operating modes with very different design implications.

V2L: Vehicle to Load

V2L is the simplest form of bidirectional EV use. The vehicle powers appliances or equipment via an adapter plugged into a standard AC socket on the car or via a dedicated outlet on the charge port. No home wiring integration, no utility agreement, no inverter coordination.

V2L output is limited and varies by vehicle, so check the owner’s manual for the rated output. It is useful for job sites, outdoor events, and emergency loads during power outages, but it has no place in a grid-tied solar system design. V2L does not interact with the solar inverter, the home panel, or the meter.

V2H: Vehicle to Home

Vehicle-to-home (V2H) connects the EV battery to the home’s internal wiring, powering the house when the grid is down or during peak tariff periods. It requires an automatic transfer switch (ATS) or a specialized V2H gateway that disconnects the home from the grid before activating EV discharge.

The isolation requirement means V2H typically operates in island mode: the home is electrically separated from the grid during EV discharge. This eliminates the need for a utility interconnection agreement in most markets, simplifying the regulatory path considerably. For solar system design, V2H adds a layer of complexity: the solar inverter must also enter island mode and synchronize with the EV’s AC output when the grid is disconnected. Not all hybrid inverters support this behavior out of the box.

V2G: Vehicle to Grid

V2G is the full bidirectional mode. The EV discharges to the utility grid, generating revenue from grid services such as frequency regulation, demand response or time-of-use arbitrage. This requires:

1. A utility interconnection agreement for bidirectional export
2. A grid-compliant bidirectional inverter certified for export
3. A smart meter that measures and timestamps bidirectional flows
4. A home energy management system (HEMS) to schedule dispatch

V2G is the only mode with direct revenue potential from grid services. It is also the most complex, the most expensive to install, and the least uniformly supported by utilities as of 2026. Most operational V2G programs remain in pilot phase.

The practical starting point for most installers in 2026: design for V2H capability with hardware that can be upgraded to V2G. This future-proofs the installation and avoids regulatory delays while delivering immediate backup power value to the client.

How V2G Rewrites Solar System Design Rules

This is where V2G has the most direct impact on daily design work. Four areas change fundamentally.

Inverter Selection and Sizing

A standard string inverter is unidirectional. DC from the panels converts to AC and flows to the home or grid. It cannot accept energy from the AC side and push it back to DC, and it cannot discharge an EV battery.

V2G solar systems require a hybrid inverter, an inverter with a bidirectional DC bus and typically a battery port. The hybrid inverter manages power flow among three sources: solar panels (DC), battery or EV charger (DC), and the grid (AC). When the EV is discharging, the hybrid inverter routes that energy to AC loads and, if export is permitted, to the grid.

V2G-capable hybrid inverters and bidirectional chargers are sold as ecosystems, and each one supports only certain chargers and vehicles. Specify the inverter and charger together, and check each manufacturer’s compatibility list on its own website.

Combined inverter capacity is a constraint installers frequently overlook. Many distribution networks cap the total inverter capacity for small embedded generation. In a hypothetical case, a 5 kW solar inverter plus a 10 kW V2G charger totals 15 kVA, which may trigger a larger embedded generation application that needs network operator approval and can take weeks or months. Check your local network’s technical standard before specifying equipment. Some networks, such as SA Power Networks in Australia, publish a dedicated page on bidirectional and V2G charging.

The anti-islanding paradox is the other inverter challenge. Solar inverters must shut down when the grid fails. This anti-islanding protection exists to protect line workers and is required in most markets. But V2H island mode needs the inverter to continue operating when the grid is absent. The usual resolution is a smart inverter with grid-forming capability that tells a controlled disconnection (intentional island) from an uncontrolled grid fault. Not all hybrid inverters support both behaviors, so check the datasheet for grid-forming capability before specifying one.

Solar Array Sizing with V2G Loads

Standard PV array sizing uses one equation: annual household consumption divided by specific yield for the location. V2G adds two more loads to that calculation: EV charging demand and V2G discharge reserve.

EV charging load. An EV driven 40 km per day at 6 km/kWh consumes approximately 7 kWh of battery per day. At 100 km per day, that rises to roughly 17 kWh. If the client wants to charge the EV entirely from solar, the only configuration that makes environmental sense for V2G, the array must cover that load in addition to the household.

Assume a specific yield of 1,100 kWh/kWp per year, a plausible figure for central Europe that you should replace with your site’s modeled yield. Covering 7 kWh/day of additional load requires roughly 2.3 kWp of extra solar capacity. Covering 17 kWh/day requires approximately 5.6 kWp. These are material additions to what would otherwise be a standard residential system size. For European funding context, see European solar incentives.

V2G discharge reserve. If the system is designed for V2G dispatch in the evening peak (for example 17:00 to 21:00), the EV must arrive home with enough charge to fulfill both the V2G dispatch target and retain a safe minimum state of charge, commonly set around 20%, but check the vehicle and charger settings. The solar array must be sized to refill the battery after each V2G discharge event, on top of covering household loads.

Worked example (all inputs are assumptions): client drives 50 km per day (8 kWh consumed), V2G dispatch target is 15 kWh per evening, minimum SoC reserve is 20% (13 kWh on a 65 kWh battery). Total daily charge required: 8 kWh (driving) + 15 kWh (V2G dispatch) = 23 kWh. Household load: 12 kWh/day. Total solar output required: 35 kWh/day. At 1,100 kWh/kWp annual yield (about 3 kWh/kWp per day), that requires approximately 11.6 kWp. A household-only design for the same 12 kWh/day load would need about 4 kWp, so the V2G scenario is close to three times larger.

Orientation and tilt. In a V2G-optimized design, the timing of solar generation matters as much as total annual yield. West-facing panels shift output toward the afternoon, which aligns with the window when the EV is home and being charged before the V2G dispatch window opens. A split array, south for maximum annual yield, west for afternoon peak generation, can outperform a pure-south array in a V2G context. Model it against the client’s TOU tariff before you decide.

System Coupling Strategy

Three practical configurations exist for solar combined with V2G:

DC-coupled (new build, preferred). Solar panels connect to a shared DC bus. The hybrid inverter manages the bus and handles AC conversion. The V2G charger connects to the DC bus directly, charging and discharging the EV battery without any AC conversion overhead. Efficiency is generally higher because there are fewer conversions. Requires a DC-coupled V2G charger that your inverter supports. Best for new-build systems where the full architecture can be specified from scratch.

AC-coupled (retrofit, flexible). The existing solar inverter converts panel output to AC. The bidirectional EV charger connects to the home’s AC bus. Each power conversion adds losses: solar DC to AC, then AC to DC into the EV, then DC to AC on discharge. Round-trip efficiency in AC-coupled V2G is lower as a result. It still works with any existing solar installation and any AC bidirectional charger. Best for retrofits.

Hybrid AC+DC. Solar and a stationary battery share the DC bus via a hybrid inverter. The V2G charger is AC-coupled on the AC side. This is the most common configuration in practice right now, it allows a separate stationary battery for islanding and fast response alongside the EV for bulk storage and V2G. Efficiency falls between the two architectures above. See the commercial battery storage sizing guide for sizing the stationary battery component in a hybrid setup. If you are adding storage as a service line, see adding battery storage services.

For most residential V2G installs in 2026, the hybrid AC+DC architecture is the pragmatic choice, it works with a broad range of EVs and chargers and does not require the client to have a DC-bidirectional-capable vehicle.

Grid Connection and Export Controls

V2G changes the site’s relationship with the grid connection. A solar-only system exports during the day. A V2G system can export during the day (solar) and during the evening (EV discharge). The combined peak export of solar plus V2G can exceed the agreed export limit if not properly controlled.

CT clamp at the grid connection point. A current transformer sensor mounted at the utility meter monitors real-time import and export. The HEMS reads this data continuously and adjusts EV charge and discharge rates to prevent the combined export from exceeding the agreed connection limit. This is the same function used in solar export-limit control setups, but applied to bidirectional flows in both directions.

Smart meter. A standard accumulation meter cannot distinguish between imported and exported energy in the same interval. A smart meter with interval data recording is generally needed for any V2G installation. The meter timestamps import and export separately, enabling TOU billing and V2G revenue tracking. Metering requirements for embedded generation, including V2G, differ by market, so ask the network operator which meter type it requires.

HEMS dispatch logic. The home energy management system is the operational brain of a V2G solar installation. It monitors solar generation, EV state of charge, household load, grid prices, and any utility dispatch signals, then decides in real time whether the EV should charge (absorb solar surplus), hold (preserve V2G capacity), or discharge (export during peak). Without a HEMS, V2G is uncontrolled, the EV charges and discharges without optimization, undermining both the financial case and grid stability compliance.

Compatible EVs and Chargers in 2026

V2G compatibility depends on the vehicle, the connector, the charger firmware and the vehicle maker’s warranty terms. Model-by-model support changes quickly and is published only on each manufacturer’s own site, so this guide does not list models or power ratings. Use the table below as the checklist for every project.

CHAdeMO is an older connector, and newer bidirectional designs generally target CCS2 with ISO 15118-20. Check the vehicle maker’s current documentation before assuming a specific model supports V2G.

Charger and inverter ecosystems. Several solar and storage manufacturers sell bidirectional chargers designed to work with their own inverters and energy management software. In practice this means the inverter brand often decides which charger you can use. Read the compatibility list on the manufacturer’s own site, and do not assume a charger that works with one ecosystem will work with another.

The Financial Case for V2G Solar

V2G changes the financial model of a solar installation in two ways: it adds a revenue stream through grid services and it replaces or supplements stationary battery storage.

Equipment Cost Premium

A bidirectional V2G charger costs more than a standard Level 2 home charger because it carries more power electronics and certification. Installed prices vary by market and product, so get written quotes rather than relying on a general range. The payback example below uses assumed prices for illustration only.

The stationary battery comparison is the right frame for clients already considering storage. A V2G charger gives access to a large, dynamic EV battery rather than a fixed home battery. For clients who need an EV charger anyway, the relevant question is not “is V2G worth the full price” but “is the premium over a standard L2 charger worth it.”

Revenue Sources

V2G generates revenue through three mechanisms:

Frequency regulation. The EV charges and discharges quickly in response to grid frequency deviations. Per the US Department of Energy’s FEMP page on bidirectional charging, PJM pays the University of Delaware roughly $1,200 per year per battery electric vehicle available. This is a program-specific figure, not a guarantee, and it requires access to a utility or aggregator frequency regulation market.

Time-of-use arbitrage. Charge during off-peak hours at a cheap import rate and discharge during peak hours to avoid expensive imports or earn export premiums. As an assumption, a 15 kWh daily discharge and a 15p/kWh tariff spread would add about £820 per year (15 x 0.15 x 365).

Demand response. The utility pays participants to reduce or shift load during peak grid events. V2G supports demand response by shifting EV charging off-peak and discharging during events. Revenue depends on event frequency and program structure, so ask the program operator for its published terms.

Payback Calculation

Simple payback on the V2G charger premium over a standard L2 charger. Every input below is an assumption for illustration, not market data:

This assumes the client joins a utility V2G program, which is still not universally available. With only the £600 TOU saving, the same premium takes about 10.5 years to pay back.

The honest client conversation: V2G economics improve where a paid utility program exists, are marginal where only TOU arbitrage is available, and are unproven where no V2G market has launched yet.

Use the generation and financial tool to build the financial model for a specific project. SurgePV’s public materials do not list V2G-specific modeling, so treat V2G revenue as a separate scenario and bring the result into the proposal.

Regulatory and Interconnection Considerations

V2G sits at the intersection of EV regulation, distributed generation rules, and utility interconnection requirements. None of those frameworks were originally written with V2G in mind, and the alignment is still incomplete in most markets as of 2026.

Key Technical Standards

ISO 15118: The EV-charger communication protocol. Defines power scheduling, authentication, and in the -20 variant, DC bidirectional flow parameters. V2G without ISO 15118 cannot coordinate charge and discharge scheduling between the vehicle and the HEMS.

IEEE 1547 (US): Sets technical requirements for interconnecting distributed energy resources, which can include bidirectional EV chargers. It covers voltage, frequency and islanding behavior. Check which edition your state’s interconnection process references.

AS/NZS 4777.2 (Australia): The inverter grid-connection standard. Check the current edition and your network’s rules for bidirectional flows.

Other grid codes. In Europe, national and network operator grid codes govern export. Ask the operator which standards apply to bidirectional chargers.

Market-by-Market Status

United Kingdom. The government’s EV smart charging action plan uses the term V2X for energy exported to a home, building, other loads or the grid. Notification rules (G98/G99) and supplier tariffs for V2G change, so check with the network operator and the supplier before you design. Confirm the charger model is accepted by the operator before connecting.

European Union. Rules for charging infrastructure reference ISO 15118, but V2G export frameworks vary by member state. Several European markets have run V2G pilots, and availability differs by country and supplier. Check the national rules and the local network operator.

United States. FERC Order No. 2222, issued in September 2020, lets aggregations of distributed energy resources, including electric vehicles and their charging equipment, take part in organized wholesale markets. Implementation differs by grid operator and region, so check the local market rules.

Australia. Networks are publishing their own requirements. SA Power Networks has a page on bidirectional and V2G charging on its network. Other networks have their own rules.

The practical advice is the same everywhere: get the local network operator’s V2G interconnection requirements in writing before finalizing the design. Requirements vary by operator within a country, not just by country.

How Solar Design Software Must Adapt for V2G

Standard solar design software models a unidirectional system: panels generate DC, inverter converts to AC, household consumes, surplus exports. The model assumes energy flows in one direction. V2G breaks that assumption entirely.

A V2G solar system has energy flowing in multiple directions across the day. Solar exports during the morning. The EV charges from solar in the afternoon. The EV discharges to the home in the early evening. Export surplus from V2G discharge flows to the grid. The HEMS switches among these states in real time based on prices, generation, and grid signals.

Modeling that system requires inputs and outputs that standard PV design tools were not built to accept.

New Variables V2G Design Software Must Handle

EV availability schedule. How many hours per day is the vehicle connected? Which days per week? A commuter vehicle connected 14 hours per day has very different V2G capacity than a shared household vehicle that is rarely home during solar generation hours.

EV state of charge on arrival. A simple assumption (EV always arrives at 50% SoC) significantly overstates available V2G capacity. Conservative modeling assumes a low arrival state of charge on high-mileage days.

V2G dispatch logic. When does the HEMS decide to discharge? The simplest logic: discharge when grid price exceeds a threshold. More sophisticated: frequency regulation mode with sub-minute intervals. The dispatch logic determines annual V2G revenue, and software must simulate it against historical TOU prices or grid event data.

TOU rate structure. V2G arbitrage depends entirely on the price spread between cheap import periods and expensive export or peak periods. Software must model the specific TOU tariff for the client’s utility.

Combined inverter capacity constraint checking. The software should flag when the specified solar inverter plus V2G charger capacity exceeds the local DNO limit, triggering a warning that a separate interconnection application is required.

Export limit compliance. The software must model the combined peak export (solar generation plus V2G discharge) and confirm it stays within the agreed export limit. If not, it should suggest reducing array size, limiting V2G discharge rate, or applying for a higher export limit.

Battery degradation under V2G cycling. Standard PV+storage software models battery degradation from normal charging cycles. V2G adds discharge cycles that can accelerate degradation if SoC is not managed. The software should model V2G cycling effects on battery capacity over the system lifetime.

What a V2G Solar Proposal Must Include

A complete V2G proposal should present:

1. Annual V2G revenue projection by service type: frequency regulation, TOU arbitrage, demand response
2. Net annual bill impact: import reduction plus export revenue
3. Optimal array size for the V2G scenario
4. Combined inverter capacity check with DNO limit flagging
5. Return on investment including V2G charger premium above standard L2
6. 10-year and 25-year cashflow with EV battery degradation modeled

Purpose-built solar design software that integrates V2G modeling is not yet standard across the industry, but it is the direction the market is moving. The generation and financial tool covers the financial modeling layer of a proposal. V2G-specific dispatch simulation is not listed among its published capabilities, so run that scenario separately.

Installers who present a complete V2G financial model, rather than a vague “saves money” claim, give clients something they can check.

Shadow analysis and site assessment also take on new significance in a V2G design context: the goal is not just to maximize annual yield but to maximize generation during afternoon hours when the EV is home and charging. West-facing array components and split orientations deserve more attention in V2G system design than in standard solar-only proposals.

Conclusion

V2G is no longer only a lab idea. Programs such as the University of Delaware’s show real grid service revenue, and bidirectional chargers are on the market. The gap between what is technically possible and what most solar installations deliver is narrowing, and installers who learn V2G design now will be ready for clients who ask about it.

Three concrete actions to take now:

• Specify hybrid inverters for all new residential solar installations, even where the client has no EV yet. The incremental cost is modest and the V2G upgrade path is clear when an EV arrives.
• Build V2G revenue estimates into financial proposals for EV-owning clients, use conservative figures from published program terms and your client’s actual tariff, and present them as contingent on a program existing in the client’s area.
• Contact the network operator before submitting any V2G interconnection application. Requirements differ by operator, and the process is often separate from standard solar notification. Ask for the approval timeline and build it into the project schedule.

The EV in your client’s driveway may already be the largest battery they own. Ready to design for it? Book a demo and see how the solar design software handles the array and roof side of a V2G-ready project.

Frequently Asked Questions

Which EVs support V2G in 2026?

Support depends on the specific vehicle, connector and charger, so check the manufacturer’s current V2G documentation for each model. CCS2 with ISO 15118-20 is the direction newer bidirectional installations are moving, while CHAdeMO is the older connector used in some early pilots. Check that the vehicle warranty allows V2G before you specify equipment.

Can I add V2G to an existing solar system?

Yes, but it usually needs equipment upgrades. You need a bidirectional charger compatible with the EV, an inverter that can manage bidirectional flow, and likely a home energy management system. Check combined inverter capacity limits with your network operator before upgrading.

Does V2G degrade my EV battery faster?

It can, depending on how the battery is cycled, and the evidence is mixed. Limiting depth of discharge and avoiding repeated deep cycles lowers the risk. Read the vehicle maker’s warranty terms for V2G before enrolling in any program.

How much can I earn from V2G grid services?

Earnings depend on the market and program, and many residential programs are still pilots. The US Department of Energy’s FEMP page says PJM pays the University of Delaware roughly $1,200 per year per available battery electric vehicle for grid support. Time-of-use arbitrage depends entirely on your tariff spread.

What standards govern V2G installation?

ISO 15118 defines how the EV and charger communicate, and its -20 part covers bidirectional power transfer. Grid-side rules include IEEE 1547 in the US, AS/NZS 4777.2 in Australia and local network operator grid codes in Europe. Check the current edition of each standard and your network operator’s requirements before designing.

Do I need a special inverter for V2G with solar?

Yes, because a standard string inverter cannot manage bidirectional power flow. V2G solar systems use a hybrid inverter with bidirectional capability, or a DC-coupled design where the bidirectional charger connects to the DC bus. The inverter must also meet your local grid code for export.

What is the difference between V2G, V2H and V2L?

V2G exports EV energy to the grid, V2H powers a home, and V2L runs plug-in loads from the vehicle. Only V2G needs a utility interconnection agreement and can earn grid-service revenue. V2H and V2L are simpler because the energy stays behind the meter.