How Many Solar Panels Do You Need to Charge an EV?

The answer to how many solar panels to charge an EV is a calculation, not a national average. The useful starting point is the electricity your driving will add at home over a year. The result then depends on how much AC energy a proposed solar design is modeled to deliver at your address and whether exact modules can fit and operate as a valid system.

That distinction matters. A vehicle’s traction-battery capacity can describe one charging session, but it does not reveal annual miles or how often charging happens at home. A panel’s nameplate wattage describes rated DC power under test conditions, not annual AC production on a South Carolina roof. Charger output describes how fast energy can move, not how much driving energy a household uses in a year.

A defensible estimate therefore uses three linked records:

1. an EV energy ledger in annual and monthly kWh;
2. a site-specific solar model in annual and monthly AC kWh; and
3. a buildable design check for exact modules, roof or ground area, inverter architecture, electrical capacity, and utility approval.

This guide shows how to build and audit those records without assuming a generic vehicle, panel, solar yield, charging-loss percentage, or utility credit.

First decide what “charge an EV with solar” means

Three different objectives often get compressed into one question. Select the objective before calculating a panel count.

Annual EV-energy offset

This is the most common grid-connected planning question: how much additional annual PV production would be modeled to equal some or all of the electricity used for home EV charging over a year?

It is an energy-accounting target. The EV may charge after sunset while the array produces during the day. Electricity still flows through the home and grid according to conditions at each moment. Whether an annual production match is financially useful depends on the applicable tariff, export treatment, and load timing—not merely equal annual kWh.

Same-time solar charging

This asks how much of an EV charging session can coincide with on-site PV output. It requires interval data or scenarios for array production, household load, EVSE power, plug-in times, and controls. A yearly kWh comparison cannot answer it.

The Department of Energy’s grid-operations guidance explains that electric generation and consumption must balance in real time. Solar output changes with sunlight and weather, while the EV is one of the home’s controllable loads. Moving a charging session into a solar-production window may increase on-site use, but it does not change the vehicle’s annual driving-energy need by itself.

Charging during a grid outage

This is a backup-system design question. The Department of Energy’s distributed-energy guidance explains why ordinary grid-connected PV uses anti-islanding protection and does not simply keep a household circuit energized when the utility grid is down. Outage charging can require compatible islanding equipment, controls, adequate solar power, storage or another grid-forming source, a protected load path, reserve rules, and commissioned operating modes.

Do not add panels to an annual-offset calculation and assume that outage charging follows. It requires a separate power, energy, electrical, and controls assessment.

For most homeowners, annual home EV energy is the correct first calculation. Same-time use and outage capability are additional design cases.

Step 1: choose one EV energy boundary

The first source of error is mixing energy measured at different places. An EV charging chain can be described at the utility meter, EVSE input or output, vehicle onboard charger, traction battery, or wheels. Conversion and accessory losses occur between some of those boundaries.

For a grid-connected home-solar comparison, the cleanest load input is usually AC electricity drawn at home for EV charging. That aligns most closely with the AC production reported by a residential PV model. Use one of the following methods and record which one was chosen.

Method A: use complete wall-energy records

A dedicated meter or a reliable EVSE energy export can provide home-charging kWh. The data should cover a representative period and include every relevant home session.

Before annualizing it, check:

• whether the record is energy drawn from the wall or energy reported as added to the battery;
• whether all household drivers and EVs use the monitored equipment;
• whether sessions from another receptacle or EVSE are missing;
• whether data gaps, device resets, account changes, or network outages occurred;
• whether the sample includes an unusual road trip, extended absence, remote-work period, or temporary commute;
• how much charging happened at work, public stations, hotels, or another residence; and
• whether cabin conditioning or other parked-vehicle use is included in the meter record.

For a representative measured period:

annualized home EV kWh = measured home-charging kWh ÷ measured days × 365

Do not annualize a short or unusual interval without scenarios. Twelve months is best when available because it captures weather, travel, school, work, and seasonal driving patterns. If only a few months exist, keep a measured case and a separate expected annual case instead of blending them invisibly.

Method B: use the exact model-year EPA label

When the vehicle is not yet owned or complete metered data are unavailable, use the exact year, model, drivetrain, wheel/tire configuration, and trim at FuelEconomy.gov or on the vehicle’s EPA label. Electric-vehicle efficiency is commonly shown as kWh per 100 miles.

The EPA’s current fuel-economy testing explanation says its label procedure assumes Level 2 AC charging and includes losses in the charging cable, EVSE, and the vehicle’s onboard charger. That makes EPA kWh/100mi a wall-energy planning value for the tested configuration.

Use:

annual home EV kWh = annual miles × (EPA kWh/100mi ÷ 100) × home-charging share

Do not add a generic charging-loss percentage to the EPA figure. Doing so would count the tested Level 2 charging-system losses twice. Real consumption can still differ because of speed, temperature, terrain, tires, HVAC use, cargo, driving style, battery conditioning, and vehicle changes. Address that uncertainty with measured data or a scenario range, not an undocumented loss adder.

Method C: use vehicle telemetry carefully

A vehicle app may report energy consumed while driving, energy added to the traction battery, or energy attributed to charging. Those are not automatically wall energy.

Before using telemetry, obtain the manufacturer’s definition for the exact metric. If it excludes conversion or standby energy between the wall and battery, use a complete measured comparison from the same household to establish the difference. Do not borrow a generic loss percentage from another vehicle, EVSE, climate, or online article.

Record both the value and boundary, for example:

• 2,100 kWh measured at home EVSE input; or
• 28 kWh/100mi from exact EPA label, includes tested Level 2 charging losses; or
• battery-energy figure, wall conversion not yet established.

The third entry is not ready for solar sizing until its boundary is reconciled.

Step 2: calculate annual miles and the home-charging share

Annual miles should reflect the vehicle that will actually charge at the house. An odometer difference over a representative year is stronger than a national mileage assumption. If the vehicle is planned, build transparent low, base, and high cases.

Include recurring and irregular travel:

• work, school, errands, appointments, and caregiving;
• regular weekend travel;
• seasonal or second-home use;
• road trips that begin with home charging;
• miles driven by another household member;
• expected remote-work or commute changes;
• a second EV or replacement vehicle within the design horizon; and
• deliberate public or workplace charging.

The home-charging share is the portion of annual driving energy expected to be supplied at this house. It is not necessarily the percentage of charging sessions. A few large public fast-charging sessions can represent more energy than many short home sessions.

If reliable records exist:

home-charging share = home charging kWh ÷ total charging kWh at the same measurement boundary

If no records exist, state the planning assumptions. For example, the base case might use an expected commute and known workplace access, with a higher case assuming workplace charging becomes unavailable. The number is a household scenario, not an eligibility or savings claim.

Create monthly or seasonal cases too

Annual kWh is useful for initial capacity, but monthly cases reveal mismatches. Driving may increase when solar production falls, or a winter commute may use more vehicle energy while the array has shorter days and different weather. PVWatts provides monthly outputs that can be compared with monthly EV scenarios.

Do not require every month’s PV output to exceed that month’s EV charging automatically. That would be a different design target and could oversize the array relative to the tariff, roof, household load, or utility program. Instead, show the tradeoff among:

• annual target coverage;
• monthly production and EV-load mismatch;
• on-site consumption versus export;
• roof and inverter constraints;
• other household loads; and
• the actual utility’s billing treatment.

Step 3: reconcile the EV with the whole house

The EV is an incremental load, but the final solar system serves a meter, not a label attached to the car. A proposal should begin with the home’s complete 12-month utility history, then identify loads that are already in those bills and loads that are not.

This avoids four common errors:

1. Double counting an existing EV. If the car has charged at home throughout the billing history, much or all of its load is already inside the household kWh.
2. Omitting a planned EV. If the car arrives after the bill period, its expected home-charging energy must be added as a future load.
3. Adding two independent arrays. “House panels” plus “EV panels” may ignore the same inverter, service, roof, interconnection, and tariff constraints.
4. Ignoring other changes. Heat-pump equipment, water heating, a pool, an addition, a second EV, efficiency work, or occupancy changes may be larger than the vehicle adjustment.

Use an EV sub-ledger so the assumption remains visible, but integrate it into the complete load model before final design. The solar system sizing guide covers that whole-home reconciliation, target-offset decision, roof/layout checks, and final system documentation in greater depth.

A useful load table looks like this:

Load item	Present in 12-month bills?	Annual or scenario kWh source	Treatment
Existing household use	Yes	Utility bills	Keep once
Existing EV home charging	Usually yes if charged during bill period	EVSE/meter reconciliation	Identify, do not add twice
New or replacement EV	No or only partly	Exact EPA or measured scenario	Add documented home share
Second future EV	No	Low/base/high scenario	Model separately
Other electrification	Depends	Equipment/use model	Add or remove explicitly
Efficiency changes	Not yet	Documented project assumption	Subtract only with support

The final load model should show the historical total, every adjustment, and the resulting design load. “We added panels for the EV” is not an audit trail.

Step 4: get an address-specific PV production model

PV capacity is stated in DC kW, while the useful annual comparison is modeled AC kWh. The conversion depends on the site and complete design. NREL’s current PVWatts model accepts location and system inputs and returns annual and monthly AC energy, with acknowledged uncertainty.

Record at least:

• exact address or map point and selected weather data source;
• modeled DC system capacity;
• module and array type settings;
• roof plane or ground-mount tilt and azimuth;
• system-loss assumption and every adjustment to it;
• DC-to-AC ratio and inverter-efficiency input;
• shading treatment and the source of shade data;
• annual AC kWh;
• each month’s AC kWh; and
• model version and run date.

PVWatts is a screening and estimating model, not a structural survey, shade measurement, final electrical design, or production guarantee. A proposal should explain how field conditions and the exact equipment modify the model.

Calculate specific yield

Run a documented candidate system, then calculate:

modeled specific yield = modeled annual AC kWh ÷ modeled DC kW

The result is annual modeled AC kWh per installed kW DC for that case. Keep it tied to the recorded inputs. Do not turn it into a permanent statewide number or use a generic “peak sun hours” shortcut.

If the roof has multiple orientations, meaningful shade differences, or separate arrays, model them accordingly. One south-facing roof-plane result should not be applied to modules placed elsewhere without checking the effect.

Step 5: convert EV kWh into incremental PV capacity

Once the annual home EV load and site-specific yield share compatible energy boundaries:

incremental PV DC kW = target annual home EV kWh ÷ modeled specific yield

The target can be less than, equal to, or more than the base-case EV load only when the homeowner understands why. A contract should not silently convert “offset my EV” into a fixed-output, bill, or environmental promise.

Next convert the DC capacity to the exact proposed module:

arithmetic module count = incremental PV DC watts ÷ exact module watts

Use the nameplate value from the exact manufacturer data sheet, not a market average or sales label. A current Qcells module data sheet, for example, publishes several power classes along with different electrical and physical specifications. That illustrates why “a 430-watt panel” is not a complete product or design description. This is not a product recommendation or a statement about what Sunburst currently supplies.

A worked example—not a panel-count recommendation

The following inputs are invented only to demonstrate the method. They are not South Carolina averages, a production claim, or a recommendation for any driver or property.

Assume:

• 10,000 annual miles;
• an exact model-year EPA figure of 30 kWh/100mi at the wall;
• 75% of charging energy supplied at home;
• a separately documented PVWatts case producing 1,450 annual AC kWh per installed kW DC; and
• a hypothetical exact 430 W DC module.

EV calculation:

10,000 miles × (30 kWh ÷ 100 miles) × 0.75 = 2,250 home EV kWh/year

PV capacity calculation:

2,250 kWh ÷ 1,450 kWh per kW DC = about 1.55 kW DC

Module arithmetic:

1,550 W ÷ 430 W/module = about 3.61 modules

The answer is not automatically four panels. The designer should model feasible adjacent whole-module options. Three modules would be 1.29 kW DC; four would be 1.72 kW DC. Their actual annual and monthly outputs must be rerun using the proposed layout and inverter design.

Why might the selected design differ from a simple round-up?

• The usable roof plane may fit three modules but not four without violating an applicable pathway, setback, edge, obstruction, or mounting constraint.
• The exact inverter, optimizer, or microinverter may impose string, branch, voltage, current, power, or compatibility rules.
• A four-module option may use a different roof plane or shade condition, changing specific yield.
• The home’s complete load and desired solar target may make additional capacity useful—or reveal that the EV load was already counted.
• The current utility program or interconnection process may treat a revised system differently.
• A future second EV or higher home-charging share may justify preserving a documented expansion path rather than guessing now.

The purpose of the arithmetic is to create testable designs, not to bypass design.

Step 6: test whether the module count can become a system

A mathematically tidy count can fail in the field. Require the proposal to connect the EV load worksheet to a buildable design.

Roof and site fit

The installer should verify:

• exact module dimensions and required mounting zones;
• usable roof-plane geometry, edges, ridges, hips, valleys, vents, skylights, chimneys, dormers, and equipment;
• applicable access pathways, setbacks, and fire-safety requirements as interpreted by the filing authority;
• roof condition, remaining service life, deck and structural findings, and attachment plan;
• shade through relevant seasons, not one photo or a map pin alone;
• drainage, debris, wind exposure, salt/coastal conditions, and maintenance access;
• ground-mount land, trench, easement, soil, drainage, access, and approval constraints when applicable; and
• the opportunity cost of occupying the best remaining roof area with a small expansion.

Panel wattage alone cannot establish whether a higher-watt module uses roof area more effectively. Compare exact dimensions, placement, modeled production, electrical fit, warranty/service implications, and availability in the proposed bill of materials.

Inverter and electrical fit

The proposal should state:

• exact module, inverter, optimizer or microinverter models;
• DC and AC ratings relevant to the proposed configuration;
• string length or branch-circuit design and manufacturer compatibility evidence;
• expected clipping or limiting assumptions in the production model;
• rapid-shutdown and other applicable system requirements;
• service/panel interconnection method and capacity basis;
• monitoring architecture and how added production and EV charging will be distinguished;
• whether the design modifies an existing system or creates a separately interconnected system; and
• which existing warranties, service agreements, financing documents, or provider permissions apply.

This is professional design scope, not a homeowner wiring exercise. Do not select string lengths, conductors, breakers, interconnection equipment, or service modifications from an online panel-count formula.

Permitting and utility fit

The South Carolina Energy Office’s interconnection guidance says a grid-connected solar system requires utility interconnection and directs consumers to the actual utility for specific procedures. Adding modules to an existing system can trigger a new or amended review; the result depends on provider rules, equipment, capacity, program, and filing date.

Identify the utility from the account—not the nearest city—and ask for current documents covering:

• allowed or reviewed capacity and the calculation basis;
• new-system versus existing-system expansion treatment;
• interconnection application, technical data, diagrams, fees, studies, inspections, meter work, insurance, and permission to operate;
• tariff or rider governing imports, on-site use, and exports;
• time-of-use periods, demand terms, minimum charges, or other account conditions;
• treatment of production above load in each relevant interval or billing period;
• program assignment when equipment or ownership changes; and
• what must be approved before purchase, installation, energization, or operation.

Dominion Energy South Carolina, for example, currently publishes residential-solar sizing and time-of-use information as separate resources. That demonstrates why a production model and a rate analysis are different records. It does not show that a reader has a Dominion account, qualifies for a program, will receive a particular system size, or will save a stated amount.

Use Sunburst’s South Carolina utility directory to reach the provider-specific starting point, then confirm the controlling documents for the account.

Charger power does not determine annual panel count

EVSE output is power, measured in kW. Annual EV use is energy, measured in kWh. A higher configured charging power may replenish the same annual driving energy in shorter sessions; it does not automatically create more annual miles or more annual energy.

The electrical design still matters. Vehicle AC acceptance, configured EVSE output, circuit capacity, service/load calculation, parking window, controls, and other household loads determine whether the charging installation works as intended. The Level 2 charger installation guide explains that project boundary.

For solar sizing, keep the clock-time question concise:

• annual kWh determines the initial incremental energy target;
• charging power and duration determine when and how fast that load appears;
• interval overlap determines how much PV can be consumed on site during charging; and
• utility rules determine how imports and exports are measured or valued.

A seller should not multiply EVSE nameplate kW by 365 days unless the actual operating-hours assumption is documented. Nor should a seller promise a full or overnight charge without the exact vehicle, starting state, configured output, parking window, conditions, and controls.

Night charging does not automatically require a battery

A grid-connected homeowner can produce solar electricity during the day and charge an EV from the home electrical system at night. Whether that annual arrangement meets the homeowner’s economic or energy-source objective depends on the tariff and interval accounting.

A battery can shift some energy across time and may support other household objectives. It also introduces its own usable-kWh, continuous/surge-power, reserve, conversion, control, warranty, degradation, code, interconnection, and cost constraints. It should not be added just to make an annual panel-count slogan sound physically direct.

Ask these questions before assigning storage a role:

• Is the objective more on-site solar use, rate management, backup, or another outcome?
• What EV and household loads must be served, for how long, and at what power?
• Can the battery and inverter support the configured charging load in the intended operating mode?
• How much PV is realistically available to recharge storage after household load?
• What reserve must remain for backup?
• How do the utility tariff and program treat charging, storage, imports, and exports?
• What happens during a grid outage, and which circuits and controls are actually commissioned for that mode?

The answer may be schedule control, a different EVSE configuration, storage, a larger integrated project, or no additional equipment. The coordinated solar and EV charger guide covers how the solar, EVSE, electrical, controls, and approval scopes should be assigned in one project.

Existing solar needs a separate expansion review

If the home already has solar, compare the EV load with actual system production and utility bills before assuming more modules are needed. Gather:

• 12 months of utility import/export data;
• 12 months of portal production data and any meter data;
• original contract, ownership or financing documents, approved plans, equipment schedule, warranties, and permission-to-operate records;
• current roof layout and remaining usable area;
• exact inverter, optimizer, microinverter, combiner, monitoring, service, and interconnection equipment;
• known faults, replacements, shading changes, or production gaps; and
• current utility program and the effect of modifying the system.

Reconcile monitoring and bills at compatible date boundaries. A production shortfall, missing telemetry, changed tariff, or new household load should not be mistaken automatically for insufficient panel count.

Then require a written decision among:

• no expansion, because existing production and the selected target already fit;
• operational or charging-schedule changes;
• modification of the original system under supported equipment, warranty, provider, and utility terms;
• a separately designed/interconnected addition; or
• a broader replacement or roof/electrical project when the existing platform cannot support a clean addition.

Do not assume that unused inverter nameplate, an empty roof patch, or compatible-looking connectors authorize an expansion. Original ownership, warranty, manufacturer documents, code, AHJ, and utility rules all matter.

Compare proposals with the same EV-to-solar worksheet

Give every bidder the same input packet and require the output to be reproducible. A useful comparison schedule includes:

Record	Required evidence
Vehicle	Exact year/model/configuration and EPA or manufacturer source
Travel	Odometer history or low/base/high annual-mile cases
Charging	Measured home kWh or documented home-charging share
Energy boundary	Wall AC, EVSE, or battery value clearly identified
Existing household	12 monthly bills and identified abnormal periods
Future loads	EV and other additions shown once with source and date
Solar model	PVWatts version, location, weather file, DC kW, array/module type, losses, tilt, azimuth, DC/AC ratio, inverter input
Production	Annual and monthly AC kWh, plus uncertainty disclosure
Equipment	Exact modules, inverter/optimizer/microinverter, mounting, monitoring, and electrical equipment
Layout	Roof/ground plan, dimensions, shade, pathways/setbacks, structural and roof assumptions
Utility/AHJ	Provider, current program/tariff, interconnection path, permit authority, open conditions
Alternatives	Feasible adjacent whole-module cases and reasons for selection
Acceptance	Approved documents, installed equipment, monitoring, production baseline, EVSE test, owner records, and open-item list

Ask the bidder to show every formula. If a proposal states “six panels for the car,” request the miles, kWh/100mi or measured charging record, home share, annual EV kWh, PV model inputs/output, module model/wattage, whole-house reconciliation, and utility assumption behind six.

Also ask the bidder to distinguish:

• modeled annual production from any contractually stated performance commitment;
• solar DC capacity from inverter AC power;
• annual EV energy from EVSE configured power;
• same-time self-consumption from annual offset;
• equipment nameplate from field layout; and
• incentive or tariff assumptions from the installed contract price.

The solar cost calculator can be useful for an early household screen. It does not replace exact vehicle inputs, a complete bill ledger, an address-specific design, or the current utility program.

When the project is ready—and when it should wait

A solar-plus-EV assessment is ready when the homeowner can provide the exact vehicle or a transparent vehicle scenario, credible annual miles, a home-charging plan, current bills, site access, and the actual electric utility. It is especially useful before ordering a vehicle charger or solar equipment, modifying an existing array, or comparing proposals with different panel counts.

The project should pause before contract commitment when:

• the vehicle configuration or home-charging share is unknown and materially changes the load;
• EV energy data have an undefined measurement boundary;
• the car’s charging is already in the bills but is being added again;
• the PV model uses a generic regional yield with no recorded site/design inputs;
• the exact module or inverter has not been identified;
• roof, structural, shade, electrical, ownership, or warranty constraints remain unexamined;
• the actual utility, program, or interconnection path is unknown;
• a proposal promises direct solar charging, outage charging, production, or savings without a corresponding system and tariff analysis; or
• quotes use different EV miles, target coverage, equipment, layout, exclusions, or acceptance conditions.

Sunburst publishes both residential solar installation and EV charger installation services, which supports a combined review without assuming that every home needs more PV, a service upgrade, a battery, or a particular product. Bring the EV energy ledger, 12-month bills, site information, and competing designs. To turn those records into a property-specific solar-plus-EV scope, request a free assessment.

Solar panels for EV charging FAQ

Can I size solar from the EV battery capacity?

Battery capacity can help describe a particular charging event, but it is usually the wrong primary input for annual home solar. Annual miles, energy consumption per mile, and the share charged at home describe the recurring load. A driver rarely uses exactly one zero-to-full battery cycle on a fixed schedule, and public charging changes the home requirement.

Does EPA kWh/100mi include charging loss?

EPA says its current label procedure assumes Level 2 AC charging and includes losses in the cable, EVSE, and onboard charger. When using the exact model-year EPA value, do not add a generic charging-loss percentage. If using vehicle telemetry or battery energy instead, identify that measurement boundary and reconcile it to wall energy with supported data.

Should I use daily miles or annual miles?

Use annual miles for the initial annual-energy calculation, supported by monthly or seasonal scenarios. Daily miles can help design the charging window and test high-use days, but one commute day multiplied blindly across a year can miss weekends, trips, remote work, absences, seasonal changes, and public charging.

Do higher-wattage panels always mean fewer panels?

The arithmetic count falls when exact module watts rise and all other inputs stay equal. A buildable result still depends on module dimensions, roof placement, shade, inverter compatibility, branch or string design, utility review, availability, and modeled AC production. Compare complete candidate designs, not wattage alone.

If I charge at night, are the panels charging my EV?

Not at the same moment unless an appropriately designed energy-storage and control path supplies the load. A grid-connected annual analysis can compare daytime PV production with nighttime EV use over a billing or annual period, but the grid and tariff mediate the intervals. Describe the claim as annual offset or production matching, not direct nighttime solar charging.

Do I need a home battery to pair an EV with solar?

No universal rule requires a battery for grid-connected solar and home EV charging. Storage may support time shifting, backup, or another objective, but it must be sized for usable energy, power, reserve, recharge, controls, and the exact operating mode. It should be evaluated as a separate design decision.

Will solar charge my EV during a power outage?

Do not assume so. Ordinary grid-connected PV is designed to stop energizing the grid during an outage. Charging in an islanded mode requires specifically compatible equipment, controls, protected circuits, adequate available power/energy, and commissioning. An annual panel count does not prove outage operation.

Should the array cover the EV’s worst winter month?

Only if that is an explicit, analyzed objective. Designing every month to cover EV charging can create excess production at other times and may not fit the roof, whole-house load, utility program, or economic goal. Compare annual and monthly cases and state the selected target.

How should I plan for a second EV?

Create a separate future scenario with the likely vehicle efficiency, annual miles, home share, and timing. Show how it affects the household load, PV capacity, roof use, inverter/electrical path, EVSE controls, and utility limits. Do not silently inflate the current design under the label “future-proof.”

Is the panel count final after dividing by module wattage?

No. That calculation produces a candidate count. The installer must test feasible whole-module layouts with exact equipment, model their production, verify roof/structural/electrical conditions, and confirm permitting and utility interconnection. The selected proposal should explain why its count is preferable to adjacent feasible options.

Turning the EV calculation into a Sunburst design

The arithmetic in this guide gives you a defensible target. Turning it into a system is where a South Carolina design either holds up or collapses: usable roof planes after setbacks and fire pathways, measured shade, inverter and string limits, service and panel capacity, and what your utility allows for the resulting system size. Sunburst models your actual address and roof, then shows the module count that can genuinely be installed alongside the one the arithmetic suggested.

Adding EV load to an existing array is a separate review — expansion is not always straightforward, and the interconnection may need to be reopened. We handle that as its own scope rather than assuming panels can simply be added.

Sunburst designs, permits and installs residential solar and EV charging statewide from Daniel Island, with an average residential system around 9.5 kW and every install under our lifetime full-system and roof-penetration warranty. Read next: system sizing from your kWh and the combined solar-plus-EV project. For the local version, see EV charger installation in Myrtle Beach or Florence. Book a free assessment for an address-specific answer.

Sources and methodology

This guide was researched on August 10, 2026. The complete live Sunburst sitemap and the local coordinated solar-and-EV, Level 2 installation, whole-home system-size, calculator, service, city, and live cost content were audited before drafting to prevent duplicated intent.

Vehicle-energy boundaries were checked against the EPA fuel-economy and EV range testing methodology, the EPA electric-vehicle label guide, and the DOE Alternative Fuels Data Center. Solar modeling and system behavior were checked against NREL PVWatts V8, DOE solar PV and grid-integration resources, the South Carolina Energy Office interconnection guidance, current utility resources, and current manufacturer technical documentation.

Vehicle specifications, household use, weather data, model versions, module/inverter products, roof conditions, code interpretations, tariffs, programs, and interconnection rules can change. The exact current documents, field findings, filing authority, utility, approved design, and signed contract control a project. The worked example is hypothetical and teaches the method; it is not an estimate for a reader’s home.