A separate commercial EMS makes sense when its performance can improve how the battery responds to site demand, grid tariffs and equipment behind the meter.
Below, find our answers to the 13 questions from commercial solar installers and EPCs.
If the inverter already controls the battery, what does a separate EMS add to a commercial battery project?
A separate EMS can make site-level decisions that the inverter’s built-in controls may not handle. The inverter still charges and discharges the battery, while the EMS uses site demand, solar output, tariff rates, import and export limits, and battery reserves to decide when that should happen. Whether it adds anything depends on how capable the inverter controller already is.
What the inverter may already do
Most commercial inverter packages can handle more than power conversion. Depending on the model and controller, they may already provide:
- timed charging and discharging
- solar self-consumption
- minimum state-of-charge settings
- export limitation
- simple peak shaving against a fixed threshold
That may be enough for a site with a predictable load and a simple tariff. The battery can charge during the same low-rate period each night and discharge during the same higher-rate period each day.
The standard control hierarchy for battery storage places the EMS above the inverter. The EMS calculates the required charge or discharge power, while the inverter carries out the command within the battery limits set by the BMS.
What a separate EMS changes
A separate EMS becomes useful when the best battery schedule changes from one day or half-hour to the next.
It can read import and export at the site connection point, use the customer’s actual tariff, forecast site demand and solar generation, and keep enough charge available for a later requirement. It can then update the battery schedule when the forecast or the real site load changes.
For example, a fixed schedule may start discharging the battery at 4pm every day. An EMS may hold some charge back if the load forecast shows that the site’s largest peak will arrive at 6pm. It may also increase overnight charging when poor solar generation is expected the next day.
Research into behind-the-meter battery dispatch found that the best control method changes with the tariff, load profile, solar generation and battery cycling cost. A more advanced controller therefore needs to make better decisions for that specific site, rather than simply add more software.
Before specifying another EMS, check whether the inverter controller can:
- read whole-site import and export
- use the full tariff
- forecast load and solar output
- change its schedule as conditions change
- accept supported third-party commands
- keep a safe fallback schedule if communications fail
GridVolt’s Energy Manager forecasts site load and solar output for 48 hours and recalculates the battery schedule every 15 minutes. One live commercial deployment recorded a 41% increase in battery savings during its first 70 days. That result shows what better scheduling achieved on that site, rather than what every project should expect.
When are built-in inverter schedules good enough for a commercial battery?
Built-in inverter schedules are usually good enough when the battery has one repeatable job, the tariff periods stay fixed and the site follows a consistent load pattern. The installer should still test the proposed charging and discharging times against recent interval data, because regular opening hours do not always produce a regular site peak.
When a fixed schedule can do the job
A built-in schedule can work well when the installer can set the same operating rule for most working days.
Typical examples include:
- charging during the same low-rate period each night
- discharging during the same higher-rate period
- storing predictable daytime solar surplus for later use
- keeping a fixed minimum state of charge
- reducing a peak that occurs at roughly the same time each day
Many built-in battery controllers allow charging and discharging rules to be set by day and time. That type of control may be enough where tariff windows, operating hours and site demand remain stable.
The installer still needs to check whether the price difference covers inverter losses, battery losses and the cost of cycling the battery. A schedule that charges at 15p per kWh and avoids electricity costing 16p per kWh is unlikely to produce a worthwhile saving once those losses are included.
Check what the manufacturer controller already includes
Built-in control does not always mean a simple timer. Some commercial manufacturer packages already use a meter at the site connection point and adjust battery output against live site demand.
Some commercial battery controllers can combine self-consumption and peak shaving while reserving separate parts of the battery for each job. Where the manufacturer controller already covers the project requirements, another EMS may repeat functions the site already has.
Before relying on the built-in controls, check:
- whether the daily peak falls inside the planned discharge window
- whether weekends and seasonal changes alter the load pattern
- whether the schedule still works on unusual production or occupancy days
- whether the battery has enough usable capacity to complete the planned job
- whether recent half-hourly or quarter-hourly data supports the assumption
Research into commercial battery dispatch found that battery savings change with the tariff, load profile, solar output and control method.
When the best charging plan changes with tomorrow’s load, solar generation, tariff or other battery commitments, a fixed schedule has reached its limit.
When is it worth adding a separate EMS to a commercial battery?
A separate EMS is worth adding when the extra annual saving or income it is expected to produce comfortably exceeds the controller, metering, integration, software and support costs. The comparison must use the inverter manufacturer’s best available controls as the baseline, because those controls may already cover some or all of the project requirements.
Start with the controls already included
Many commercial battery packages already provide more than fixed charging times. Depending on the manufacturer and model, the controller may include:
- solar self-consumption
- peak shaving against site demand
- time-of-use charging
- minimum state-of-charge reserves
- control across several inverters
- combined operating modes
Some manufacturer-supplied battery controllers can divide battery capacity between self-consumption and peak shaving. Adding another EMS would make little sense if the existing controller already performs every job included in the financial model.
GridVolt reviews what the existing controller already does and uses that as the baseline for comparing Energy Manager. The installer does not need to investigate the underlying control logic.
Compare the extra benefit with the full cost
Model the same battery twice. The first model should use the manufacturer’s best available control method. The second should use the proposed EMS.
Both models should use the same:
- half-hourly or quarter-hourly site data
- tariff and export price
- solar generation
- usable battery capacity
- charge and discharge power
- import and export limits
- efficiency and degradation assumptions
Research into behind-the-meter battery dispatch found that the best control method changes with the tariff, site load, solar generation and battery cycling cost. A separate EMS is therefore more likely to add money where demand varies, solar output changes, tariff rates do not follow fixed windows or several battery uses compete for the same stored energy.
Deduct the full cost of the EMS from the additional benefit. That may include the on-site controller, extra meters or CTs, integration, commissioning, communications, software charges, maintenance and any revenue share.
Ask the EMS supplier to show the annual result with and without its controls, using the same site data and assumptions. The model should also show a downside case where forecasts, tariff spreads or expected income are less favourable.
GridVolt’s simulator can compare battery performance under different control assumptions. The useful figure is the additional saving attributed to Energy Manager after all added costs, rather than the battery project’s total saving.
Can we add optimisation software to an existing commercial battery without replacing the inverter or battery?
Yes, in many cases. The installer can keep the existing battery and inverter and add a controller that reads site and battery data before sending charge or discharge commands to the inverter. The retrofit depends on the exact inverter model, firmware and available control interface. Monitoring access alone is not enough. The inverter must also accept supported write commands.
What the existing equipment must allow
The optimisation software normally connects through an on-site controller or communications gateway. That controller reads information such as:
- battery state of charge
- available charge and discharge power
- inverter operating status and alarms
- site import and export
- solar generation
- the battery’s operating limits
It then sends the required charge or discharge instruction to the existing inverter.
Many systems use Modbus TCP or Modbus RTU. A common communication standard for inverters, batteries and meters provides shared monitoring and control models. However, Modbus support does not prove that a retrofit will work. Some devices expose monitoring registers but lock or omit the registers needed for external control.
Manufacturers may also provide their own control interface. The EMS supplier checks the technical documents for the exact model and firmware. The installer does not need to interpret register maps, API guides or individual control commands.
What the installer needs to check
Before the EMS supplier prices the retrofit, send:
- the battery, inverter and controller model numbers
- the installed firmware versions, where available
- details of the existing meter and CTs
- the current controller or operating mode
- the single-line diagram
- the battery warranty or maintenance contact
The EMS supplier then checks whether the inverter provides the required read and write access, whether extra metering or communications hardware is needed, and what happens if the controller or internet connection fails.
The EMS supplier also tests the charge and discharge instructions, battery limits, alarms and loss of communications during commissioning. An external-control interface may stop output, retain the previous command or switch to a preset value when higher-level commands stop arriving.
The installer should also check the original connection agreement if the new control method changes the site’s maximum import, export or export-limitation arrangement.
GridVolt follows this retrofit model. It adds Energy Manager and an on-site controller to compatible third-party batteries. The main battery and inverter remain in place where the compatibility check confirms the required data, write access and fallback behaviour.
How do we check whether an existing commercial battery is compatible with third-party optimisation software?
The EMS supplier checks compatibility in three stages. It identifies the exact equipment and firmware, confirms that the interface provides the required readings and charge or discharge controls, then tests the installed system under normal operation and loss of communications. A brand name, Ethernet port or Modbus connection alone does not prove compatibility.
Check the installed equipment and control interface
Start by recording the make, model and firmware version of the:
- battery and BMS
- inverter or PCS
- existing controller or gateway
- site meter and CTs
- export-limitation equipment
The EMS supplier then checks the technical interface for the exact inverter model and firmware. The installer does not need to obtain or interpret the register map, API guide or integration manual.
The optimiser normally needs to read battery state of charge, current power, available charge and discharge power, alarms and operating status. It must also be able to write the commands required for the proposed control method, such as charge and discharge power setpoints.
A common monitoring and control standard defines shared models for inverters, batteries and meters. However, manufacturers choose which functions each product supports. One inverter may expose full external control while another only provides monitoring data.
The EMS supplier also checks which controller has priority. A manufacturer EMS, export limiter or existing battery schedule may override third-party commands unless the correct external-control mode is enabled.
Test the site before approving the retrofit
The optimiser also needs an accurate view of the whole site. Check that the meter and CTs measure import and export at the correct point, use the right ratio and direction, and update quickly enough for the proposed control.
Some commercial battery systems allow third-party control through LAN or RS485, but the meter must also work with the EMS. This is why inverter compatibility alone is not enough.
Before commissioning, confirm:
- whether a gateway, protocol converter or firmware update is required
- whether third-party control affects the warranty
- what happens if the controller or internet connection fails
- whether the existing import or export controls can still override unsafe commands
The EMS supplier should start with read-only checks. It should then test small charge and discharge instructions, battery limits, alarms, controller priority and communication failure. Timeout and fallback settings form part of this integration work.
Treat the system as compatible only when the required data and commands work on the installed equipment and the failure test passes. A firmware update, new meter or gateway may make it conditionally compatible. A read-only or locked interface is not currently compatible with active optimisation.
What access does a third-party EMS need to a commercial battery inverter?
A third-party EMS normally needs read access to battery status, available power, alarms and site import or export. It also needs write access to a limited charge or discharge command. It should not receive unrestricted inverter access or permission to change battery safety limits, protection settings or grid-code parameters.
What the EMS needs to read
The EMS needs enough information to decide whether the battery can follow the next instruction.
This will usually include:
- battery state of charge
- current charge or discharge power
- available charge and discharge power
- inverter operating status
- active alarms and faults
- the power the inverter actually delivered
- whole-site import and export
The site import and export reading will often come from a separate meter at the point of connection, rather than from the inverter itself.
A standard information model for distributed energy equipment includes readings for battery status, available energy, power, alarms and operating state. The EMS supplier checks which data points the exact inverter model and firmware expose.
The EMS does not normally need individual cell voltages or unrestricted access to every BMS reading. The battery management system remains responsible for cell-level monitoring and protection.
What the EMS needs permission to change
For ordinary battery optimisation, the minimum useful write command is usually an active-power setpoint. This tells the inverter how many kilowatts to charge or discharge.
Depending on the equipment, the EMS may also need permission to:
- allow or stop charging
- allow or stop discharging
- select external-control mode
- set a command timeout
- apply a defined fallback power
A suitable external-control interface can accept an external power instruction while retaining a timeout and fallback response if commands stop arriving.
The EMS should not override:
- BMS charge, temperature or state-of-charge limits
- inverter fault shutdown
- anti-islanding protection
- approved import or export limitation
- unrelated permanent inverter settings
The EMS supplier identifies the information and controls it needs, configures the connection and tests the completed system during commissioning. This includes controller priority, rejected instructions, battery limits and loss of communications. The installer does not need to list or test individual registers or API commands.
Remote access should also remain restricted to the controller, inverter and meter that the EMS needs. UK guidance on remote access to operational equipment recommends limiting third parties to named equipment and recording their activity.
Give the EMS enough access to request a battery response, while leaving the inverter, BMS and protection equipment free to reject or reduce any unsafe command.
What equipment does a third-party EMS need on a commercial battery site?
A third-party EMS normally adds an on-site controller, connections to the inverter and site meter, a power supply and a secure internet connection. The installer may be able to reuse the existing meter, CTs and network where they provide the right measurements and communications. Extra meters, gateways or network equipment depend on what is already installed.
Equipment normally required
The on-site controller or gateway connects the battery equipment to the optimisation software. It reads the inverter and meter data, receives the latest battery schedule and sends charge or discharge commands to the inverter.
The controller normally needs:
- an electrical enclosure and suitable power supply
- Ethernet or RS485 wiring to the inverter
- a connection to the site meter
- internet access for forecasts, software updates and remote monitoring
- network protection agreed with the site’s IT team
A typical commercial site controller uses Ethernet and RS485 connections to collect measured values and send control instructions to connected equipment.
The EMS also needs an accurate measurement of whole-site import and export. This normally comes from a bidirectional meter and CTs at the site connection point. The controller uses that reading to manage peak demand, solar self-consumption and import or export limits.
Equipment that depends on the existing installation
A site with a compatible inverter interface, suitable meter and available network connection may need little beyond the controller, enclosure and communications wiring.
Other sites may also need:
- a replacement meter or new CTs
- a protocol converter where the inverter and controller use different communications
- a network switch or additional Ethernet cabling
- a cellular router where the site cannot provide internet access
- separate meters for solar, EV charging or other large loads
- digital input or output modules for external signals
- a UPS or second controller power supply where continuity requires it
A common communication standard can reduce integration work by providing shared data models for inverters, batteries and meters. It does not remove the need to check which functions each installed device supports.
Survey the inverter interface, meter, CT arrangement, network, enclosure space and available power before pricing the EMS installation. The survey should also identify who will supply, mount, connect and commission each item.
GridVolt includes an on-site controller as part of its normal delivery. Compatible batteries and inverters remain in place, while the final equipment list depends on the meter, communications and network already available at the site.
Who installs, commissions and supports the EMS controller on a commercial battery project?
A qualified electrical contractor normally mounts, powers and connects the EMS controller. The EMS supplier then configures the software, communications and battery commands. After handover, the EMS supplier handles controller and software faults, while the battery or inverter manufacturer remains responsible for faults inside its own equipment. The contract should name one company to coordinate the response.
Who installs and commissions the controller?
The electrical contractor or battery installer normally completes the physical work. This may include:
- mounting the controller and enclosure
- connecting the power supply
- installing Ethernet or RS485 wiring
- connecting the site meter and CTs
- connecting the controller to the site network
The contractor needs electrical installation skills and enough industrial network knowledge to check IP addresses, communication cables and device connections. Controller installation guidance commonly requires people who understand both electrical installation and IT configuration.
The EMS supplier or its approved controls engineer should lead commissioning. They normally:
- map the inverter, battery and meter data
- check signs, units and scaling
- load the agreed schedules and battery limits
- send controlled charge and discharge commands
- test which controller has priority
- test power, network and internet failure
- record the final settings
The battery or inverter manufacturer may need to provide register maps, enable external control or approve the final limits. A typical controller service includes configuration, pre-testing, commissioning and ongoing support.
Who supports the system after handover?
Responsibility normally splits by fault type:
- EMS supplier: Controller software, schedules, device drivers, cloud connection, data mapping and remote diagnostics.
- Local contractor: Controller power, damaged cables, network switches, meter faults and on-site controller replacement.
- Battery or inverter manufacturer: Faults inside the battery, BMS, inverter or manufacturer firmware.
- Site IT team: Router, firewall, network permissions and internet access.
The EMS supplier may identify an inverter alarm, but it may not have permission to repair or reconfigure the inverter. The same applies when a site network fault stops the controller communicating.
The contract should record the lead contact, fault boundaries, response times, site-attendance terms and who pays when another supplier’s equipment caused the fault. Without that agreement, each company may blame another when the battery stops following commands.
Where should we place the meter and CTs so a third-party EMS can measure whole-site load?
Place the main EMS meter and CTs at the site’s grid connection point, before the incoming supply divides between the site’s distribution boards. This measures the site’s net grid import and export. Where the EMS also needs gross building load, it will need separate solar and battery readings or another CT set around the common load bus.
Measuring net site import and export
On a typical three-phase site, install one CT around each incoming phase conductor. Place them downstream of the electricity supplier’s meter and incoming protection, but upstream of the first distribution point.
This metering arrangement measures all electricity crossing the site’s grid connection.
The meter must take its voltage reference from the matching phases. The CT on L1 must match the meter’s L1 voltage input, with the same rule for L2 and L3.
The installer must also:
- follow the CT manufacturer’s direction markings
- enter the correct CT ratio in the meter
- include every incomer to the controlled site
- check whether existing export-limitation equipment already uses the measurement point
- confirm that the meter communicates with the EMS
Do not assume the CT arrow always points towards the load. CT polarity markings vary between manufacturers.
Measuring actual site consumption
A meter at the grid connection shows net grid flow. It does not always show the total power the building is using.
For example, a factory may consume 500 kW while its solar panels supply 200 kW. The connection-point meter will show a 300 kW import. If the battery also discharges 100 kW, the meter will show 200 kW even though the factory still consumes 500 kW.
Where the EMS needs gross site load, the installer can use either:
- CTs around a common load bus that excludes the solar and battery feeders, or
- a grid-connection meter plus separate solar and battery measurements
Sites with several incomers, private transformers, bus couplers or generators may need more than one meter or CT set. Every route through which electricity enters or leaves the controlled site must appear in the EMS calculation.
Before commissioning, compare the EMS readings against the utility meter and switch known loads, solar and the battery on and off. Choose the CT position from the number the EMS must control, because net grid flow and gross site load differ whenever solar or the battery supplies the building.
Can a third-party EMS stay within the battery manufacturer's warranty limits?
Yes, provided the battery manufacturer permits third-party control and the EMS follows the warranty terms for that exact battery, inverter and firmware version. Staying within the BMS safety limits is only part of the job. The EMS may also need to limit daily cycles, cumulative energy throughput, depth of discharge and operating temperature.
Check the warranty before setting the controls
Start with the battery’s operating manual, technical specification and warranty document. These may set limits for:
- maximum charge and discharge power
- minimum and maximum state of charge
- depth of discharge
- operating temperature
- cycles per day or year
- total lifetime energy throughput
- approved inverter and firmware combinations
- manufacturer monitoring or data access
Some warranties end when the battery reaches a stated number of cycles or a cumulative throughput figure, even if the warranty period has not expired.
One commercial battery warranty, for example, limits cover by time, retained capacity and full-cycle use. It also excludes damage linked to incompatible equipment or unapproved changes.
The installer should also confirm that the manufacturer permits the proposed external controller. A Modbus connection or writable register does not prove that third-party operation complies with the warranty.
Configure, monitor and record battery use
The EMS should send instructions through the approved inverter or PCS interface. The BMS must keep final authority over cell voltage, current, temperature and fault shutdown.
The EMS should then track the battery’s wider warranty allowance, including:
- charge and discharge power
- state-of-charge range
- battery temperature
- full-equivalent cycles
- cumulative charge or discharge throughput
- alarms, rejected commands and operating limits
Another commercial battery warranty uses a lifetime throughput allowance and requires the battery to operate with approved equipment and within its manual.
The controller should reduce or stop battery use before an instruction exceeds the approved operating envelope. It should also preserve the dispatch, battery-response and temperature records that the manufacturer may request during a warranty claim.
Obtain written approval for the controller and proposed operating strategy before commissioning. Keep the approved limits with the EMS settings, test records and warranty documents. A third-party EMS can work within a battery warranty, but the project must prove compliance for the exact equipment installed.
Can we hold back a minimum battery reserve from optimisation and trading?
Yes. A commercial battery EMS can keep a minimum state of charge unavailable for normal optimisation and trading. The controller should apply the highest of the manufacturer’s minimum limit, the site owner’s chosen reserve and any energy already committed elsewhere. The installer must also confirm that the reserve remains protected if communications fail.
What the reserve can protect
A minimum reserve can keep energy available for:
- backup power during a grid outage
- an expected site-demand peak later in the day
- battery warranty or operating limits
- a contracted grid or flexibility service
For example, a 500 kWh battery with a 20% reserve would keep 100 kWh unavailable for normal discharge. The optimiser could use the remaining capacity for tariff savings, peak shaving or trading, subject to the inverter power limit and any other commitments.
A battery reserve setting can hold the battery above a chosen state of charge. The reserve selected for a commercial site should come from a defined requirement, such as the energy needed to cover critical loads for a set period.
A second limit may apply where part of the battery has already been committed to a grid service. GB storage availability rules exclude energy required for existing service commitments when calculating the capacity still available.
How to keep the reserve available
First, confirm where the reserve is enforced. It may sit in the:
- battery or BMS
- inverter controller
- third-party EMS
- trading contract
Where several limits apply, the controller should follow the one that retains the most energy.
The installer should also check:
- whether the inverter or local controller keeps the reserve during an internet failure
- who can change the setting
- whether a contracted service can temporarily require a higher state of charge
- whether the EMS receives an accurate state-of-charge reading
- whether the battery can recharge before the next site requirement
State-of-charge estimates can drift as the battery ages or operating conditions change. Errors in the SoC reading can affect the energy available for dispatch, so the reserve should not rely on an untested percentage alone.
Every kilowatt-hour held back reduces the capacity available for savings or trading. Set the reserve from the site’s backup, peak or contractual requirement, then test that the local controls preserve it when communications fail.
What happens to battery control if the site loses its internet connection?
If the site loses internet access but the local EMS controller can still communicate with the inverter and meter, the battery should continue under a pre-agreed local schedule or fallback rule. New forecasts, trading commands and remote monitoring may pause. If the controller also loses its local equipment connections, the inverter should switch to its commissioned fallback setting.
What should continue at the site
The battery management system and inverter continue to enforce their safety and operating limits. These controls do not depend on an internet connection.
An on-site EMS controller may also continue to:
- read the site meter
- communicate with the inverter
- follow the last downloaded schedule
- maintain a minimum battery reserve
- control site import or export against a fixed limit
- store operating data for later upload
A commercial on-site controller can continue controlling the battery during a temporary internet outage. However, the exact offline period and fallback behaviour depend on the controller, inverter and site design.
Losing the internet is different from losing the local connection between the EMS controller and the battery equipment. If the controller can no longer read the meter or send commands to the inverter, the inverter needs a separate local response.
Suitable external-control settings allow the commissioning engineer to set a communication timeout and define what power the inverter should use when external commands stop arriving.
What may pause until the connection returns
Functions that rely on cloud data or remote instructions may stop temporarily. These can include:
- updated load and solar forecasts
- revised tariff-based schedules
- battery trading instructions
- remote dashboards and alerts
- software updates
- changes made by the EMS provider
The controller should not keep following one final charge or discharge command indefinitely. It should either continue a stored schedule or switch to a defined fallback mode after the agreed timeout.
Before handover, test both an internet outage and a loss of local communications. Record the timeout, fallback schedule, battery reserve, data-storage period and reconnection checks. Also confirm whether the controller needs cellular backup or a separate power supply.
An internet failure should reduce the battery to an agreed local rule. It should not leave the inverter following an unlimited final command or stop battery control without a defined response.
How much more can a commercial battery save with optimisation software than with fixed inverter schedules?
There is no standard percentage that applies to every commercial battery. However, examples show that better control can materially increase the savings from the same hardware. One GridVolt deployment produced 41% more battery savings during its first 70 days. A separate commercial simulation produced 60% more savings than its better-performing fixed-threshold setting.
What the available comparisons show
At the GridVolt agricultural deployment, the existing battery had previously followed fixed inverter schedules. Energy Manager then used the site’s actual tariff, updated load and solar forecasts, and recalculated the battery schedule every 15 minutes.
Battery savings increased by 41% during the first 70 days. Most of the additional saving came from avoiding DUoS and Capacity Market Obligation charges that the previous schedule had missed.
That figure refers to the battery’s contribution, not the site’s whole electricity bill. If fixed schedules save £10,000 a year, a 41% increase would raise the battery saving to £14,100. It would add £4,100 rather than cut the full bill by 41%.
A comparison of dynamic and fixed peak-shaving controls used the same commercial load profile for each method. Its dynamic controller produced 60% more savings than the better of two fixed settings. One fixed threshold discharged too early, while the other left useful battery capacity unused.
This was a vendor-run simulation rather than a result that every project should expect.
Why the improvement changes between sites
The additional saving depends on:
- how much site demand changes between days
- whether tariff rates follow fixed or changing periods
- the timing of solar generation and demand peaks
- battery power and usable capacity
- what the inverter controller already does
- forecast accuracy
- conversion losses and battery degradation
- EMS controller, software and support costs
Research into battery dispatch found that no single control method performed best under every tariff and load profile. Fixed schedules can work well where site demand and tariff windows remain predictable.
For a reliable project estimate, compare the same battery under fixed and optimised control using the same interval data, tariff, solar output, reserve settings and equipment limits. Report the additional annual battery saving after deducting every EMS cost, rather than presenting one case study percentage as a standard result.
Check whether GridVolt can work with your commercial battery project
Before adding a separate EMS, GridVolt checks whether the existing equipment on-site can provide the required data and accept supported charge or discharge commands. We compare the expected additional savings with the controller, integration, software and support costs.
To review your proposal, send us:
- The battery and inverter make and model
- The installed firmware versions, where available
- The existing controller or operating mode
- The single-line diagram
- Details of the site meter and CTs
- Recent half-hourly or quarter-hourly electricity data
- The electricity tariff and export rate
- The site’s agreed import and export limits
GridVolt can then identify whether the built-in controls already cover the project, whether Energy Manager is compatible and what extra equipment or commissioning work the site may need.
Where enough site data is available, we can also compare the current fixed schedule with forecast-led control. This shows the additional battery saving separately from the savings the existing hardware already produces.
Get in touch with us today by filling out the form on this page or our contact page.