GEN24, Tauro and Verto Country Setup Menu Operating instructions

Adjusting parameters with the Fronius Solar.start app

The conventions regarding how information is presented in the document, which are set out below, have been defined in order to increase the readability and comprehensibility of the document.

Application notes

IMPORTANT! Indicates application notes and other useful information. It does not indicate a harmful or dangerous situation.

Software

Software functions and elements of a graphical user interface (e.g., buttons, menu items) are highlighted in the text with this mark up.

Example: Click Save.

Instructions for action

1Action steps are displayed with consecutive numbering.

✓This symbol indicates the result of the action step or the entire instruction.

The conventions regarding how information is presented in the document, which are set out below, have been defined in order to increase the readability and comprehensibility of the document.

Application notes

IMPORTANT! Indicates application notes and other useful information. It does not indicate a harmful or dangerous situation.

Software

Software functions and elements of a graphical user interface (e.g., buttons, menu items) are highlighted in the text with this mark up.

Example: Click Save.

Instructions for action

1Action steps are displayed with consecutive numbering.

✓This symbol indicates the result of the action step or the entire instruction.

WARNING!

Danger from unauthorized fault analyses and repair work.

This can result in serious injury and damage to property.

Fault analyses and repair work on the PV system may only be carried out by installers/service technicians from authorized specialist companies in accordance with national standards and regulations.

NOTE!

Risk due to unauthorized access.

Incorrectly set parameters can have a negative effect on the public grid and/or the grid power feed operation of the inverter and result in the loss of standard conformity.

Parameters may only be adjusted by installers/service technicians from authorized specialist companies.

Do not give the access code to third parties and/or unauthorized persons.

NOTE!

Risk due to incorrectly set parameters.

Incorrectly set parameters can have a negative effect on the public grid and/or cause inverter malfunctions and failures and result in the loss of standard conformity.

Parameters may only be adjusted by installers/service technicians from authorized specialist companies.

Parameters may only be adjusted if this has been approved or requested by the utility.

Any parameter adjustments must be made in compliance with nationally applicable standards and/or directives as well as the specifications of the utility.

The Country Setup menu area is intended exclusively for installers/service technicians from authorized specialist companies. To apply for the access code required for this menu area, see chapter Requesting inverter codes in Solar.SOS.

The selected country setup for the country in question contains preset parameters in accordance with nationally applicable standards and requirements. Changes may need to be made to the selected country setup depending on local grid conditions and the specifications of the utility.

This product is intended for use and sale outside the Province of Québec. It does not meet the French language documentation and labeling requirements of Québec's Charter of the French Language. Accordingly, Fronius International GmbH does not offer this product for sale to, or for delivery to, any address within the Province of Québec.

By placing an order, the customer represents and warrants that they are not purchasing the product for use or resale within Québec. Fronius International GmbH disclaims all liability and warranty obligations for any products operated in Québec in violation of these restrictions.

The Country Setup menu area is intended exclusively for installers/service technicians from authorized specialist companies. The inverter access code required for this menu area can be requested in the Fronius Solar.SOS portal.

Requesting inverter codes in Fronius Solar.SOS:

Open solar-sos.fronius.com in the browser

At the top right, click on the drop-down menu

Select the Show inverter codes menu item

A contract page appears on which the request for the access code to change the grid parameters for Fronius inverters is located

Accept the terms and conditions of use by checking Yes, I have read and agree to the terms of use and click Confirm & Save

After that, the codes can be retrieved in the drop-down menu at the top right under Show inverter codes

CAUTION!

Risk due to unauthorized access.

Incorrectly set parameters can have a negative effect on the public grid and/or the grid power feed operation of the inverter and result in the loss of standard conformity.

Parameters may only be adjusted by installers/service technicians from authorized specialist companies.

Do not give the access code to third parties and/or unauthorized persons.

The "Fronius Solar.start" app is needed for registration. Depending on the end device, the app is available on the respective platform.

1Start the installation in the app.

2Select the product to which the connection should be established.

3Open the access point by touching the sensor once

✓Communication LED: flashes blue.

4Select the Technician user in the User menu and enter and confirm the password for the Technician user.

5Call up the Safety and grid regulations → Country setup menu area.

6Enter the requested access code (see chapter Requesting inverter codes in Solar.SOS on page (→)) in the input field Access code country setup and click the button Activate.

7Adjust the parameters in the individual menu areas taking into account the nationally applicable standards and/or the specifications of the utility.

WLAN:

1Open the access point by touching the sensor once

✓Communication LED: flashes blue.

2Establish the connection to the inverter in the network settings.

✓The inverter is displayed with the name "FRONIUS_PILOT" and the serial number of the device

3Password: enter 12345678 and confirm.
IMPORTANT!
To enter the password on a Windows 10 operating system, the link "Connect using a security key instead" must first be activated to establish a connection with the password: 12345678.

4In the browser address bar, enter and confirm the IP address 192.168.250.181.

5Select the Technician user in the User menu and enter and confirm the password for the Technician user.

6Call up the Safety and grid regulations → Country setup menu area.

7Enter the requested access code (see chapter Requesting inverter codes in Solar.SOS on page (→)) in the input field Access code country setup and click the button Activate.

8Adjust the parameters in the individual menu areas taking into account the nationally applicable standards and/or the specifications of the utility.

Ethernet:

1Establish a connection to the inverter (LAN1) with a network cable (CAT5 STP or higher).

2Open the access point by touching the sensor once

✓Communication LED: flashes blue.

3In the browser address bar, enter and confirm IP address 169.254.0.180.

4Select the Technician user in the User menu and enter and confirm the password for the Technician user.

5Call up the Safety and grid regulations → Country setup menu area.

6Enter the requested access code (see chapter Requesting inverter codes in Solar.SOS on page (→)) in the input field Access code country setup and click the button Activate.

7Adjust the parameters in the individual menu areas taking into account the nationally applicable standards and/or the specifications of the utility.

Predefined setups can be selected in the Country setup selection menu. The selected country setup for the respective country contains preset parameters according to the nationally applicable standards and requirements. Depending on local grid conditions and the specifications of the utility, adjustments to the selected country setup may be necessary.

Parameter	Description
Country / Region	Selecting the respective country or region limits/displays the available country setups for the inverter.
Country setup	Displays the available setups per country/region. A setup is a device configuration predefined by Fronius. The selection of the country setup must be made in consideration of the applicable standards or in coordination with the grid operator.
Rated Frequency (Hz)	The rated frequency is predetermined by the country setup selection. Changing this parameter affects the stable operation of the inverter and is therefore only permitted in consultation with Fronius.
Rated Voltage (V)	The rated voltage is predetermined by the choice of the country setup. Changing this parameter affects the stable operation of the inverter and is therefore only permitted in consultation with Fronius.

Parameter	Description
Country / Region	Selecting the respective country or region limits/displays the available country setups for the inverter.
Country setup	Displays the available setups per country/region. A setup is a device configuration predefined by Fronius. The selection of the country setup must be made in consideration of the applicable standards or in coordination with the grid operator.
Rated Frequency (Hz)	The rated frequency is predetermined by the country setup selection. Changing this parameter affects the stable operation of the inverter and is therefore only permitted in consultation with Fronius.
Rated Voltage (V)	The rated voltage is predetermined by the choice of the country setup. Changing this parameter affects the stable operation of the inverter and is therefore only permitted in consultation with Fronius.

Parameter	Description
Country / Region	Selecting the respective country or region limits/displays the available country setups for the inverter.
Country setup	Displays the available setups per country/region. A setup is a device configuration predefined by Fronius. The selection of the country setup must be made in consideration of the applicable standards or in coordination with the grid operator.
Rated Frequency (Hz)	The rated frequency is predetermined by the country setup selection. Changing this parameter affects the stable operation of the inverter and is therefore only permitted in consultation with Fronius.
Rated Voltage (V)	The rated voltage is predetermined by the choice of the country setup. Changing this parameter affects the stable operation of the inverter and is therefore only permitted in consultation with Fronius.

These parameters can be used to set the grid monitoring times before the inverter is switched on.

For the set time, both the mains voltage and the mains frequency must be within the permissible range before connection is allowed.

The permissible range for the mains voltage is defined in the menu area Grid and system protection → Voltage → Startup and reconnection (see chapter Voltage).
The permissible range for the mains frequency is defined in the menu area Grid and system protection → Frequency → Startup and reconnection (see chapter Frequency).

Parameter	Range of values	Description
Grid Monitoring Time Startup	1 - 900 [s]	Grid monitoring time before the inverter is switched on during a normal start-up process in seconds (e.g., at sunrise).

Parameter	Range of values	Description
Grid Monitoring Time Reconnection	1 - 900 [s]	Grid monitoring time before the inverter is switched back on after a grid fault (see table Grid faults) in seconds (e.g., if a fault occurs in the AC grid during the day which causes the inverter to shut down).
The following errors are defined by the inverter as grid errors for this functionality:

Name	Description	StateCode name	StateCode number
Overvoltage	Mains voltage exceeds an overvoltage limit (Inner, Middle, or Outer Limit Overvoltage).	AC voltage too high	1114
Undervoltage	Mains voltage falls below an undervoltage limit (Inner, Middle or Outer Limit Undervoltage).	AC voltage too low	1119
Overfrequency	Mains frequency exceeds an overfrequency limit (Inner, Outer or Alternative Limit Overfrequency).	AC frequency too high	1035
Underfrequency	Mains frequency falls below an underfrequency limit (Inner, Outer or Alternative Limit Underfrequency).	AC frequency too low	1037
Fast Overvoltage Disconnect	Triggering of the fast surge protection (> 135%).	Grid voltage too high (fast overvoltage cut-out)	1115, 1116
Long Time Average Overvoltage Limit	Mains voltage exceeds the long-term overvoltage limit (Long Time Average Limit).	Long-term mains voltage limit exceeded	1117
Unintentional Islanding Detection.	Unintentional islanding was detected.	Islanding detected	1004

These parameters can be used to set the grid monitoring times before the inverter is switched on.

For the set time, both the mains voltage and the mains frequency must be within the permissible range before connection is allowed.

The permissible range for the mains voltage is defined in the menu area Grid and system protection → Voltage → Startup and reconnection (see chapter Voltage).
The permissible range for the mains frequency is defined in the menu area Grid and system protection → Frequency → Startup and reconnection (see chapter Frequency).

Parameter	Range of values	Description
Grid Monitoring Time Startup	1 - 900 [s]	Grid monitoring time before the inverter is switched on during a normal start-up process in seconds (e.g., at sunrise).

Parameter	Range of values	Description
Grid Monitoring Time Reconnection	1 - 900 [s]	Grid monitoring time before the inverter is switched back on after a grid fault (see table Grid faults) in seconds (e.g., if a fault occurs in the AC grid during the day which causes the inverter to shut down).
The following errors are defined by the inverter as grid errors for this functionality:

Name	Description	StateCode name	StateCode number
Overvoltage	Mains voltage exceeds an overvoltage limit (Inner, Middle, or Outer Limit Overvoltage).	AC voltage too high	1114
Undervoltage	Mains voltage falls below an undervoltage limit (Inner, Middle or Outer Limit Undervoltage).	AC voltage too low	1119
Overfrequency	Mains frequency exceeds an overfrequency limit (Inner, Outer or Alternative Limit Overfrequency).	AC frequency too high	1035
Underfrequency	Mains frequency falls below an underfrequency limit (Inner, Outer or Alternative Limit Underfrequency).	AC frequency too low	1037
Fast Overvoltage Disconnect	Triggering of the fast surge protection (> 135%).	Grid voltage too high (fast overvoltage cut-out)	1115, 1116
Long Time Average Overvoltage Limit	Mains voltage exceeds the long-term overvoltage limit (Long Time Average Limit).	Long-term mains voltage limit exceeded	1117
Unintentional Islanding Detection.	Unintentional islanding was detected.	Islanding detected	1004

Ramp rates limit the maximum rate of change of effective power in special situations. Rising ramps (Ramp-Up) limit the increase in effective power at the inverter AC output. Falling ramps (Ramp-Down) limit the reduction of effective power at the AC output of the inverter.

Note that the lowest rate of change is applied if multiple rates of change have been entered. An Irradiation Ramp can thus be rendered ineffective by, for example, a lower Startup Ramp or another function affecting the rate of change (e.g., P(U) or P(F)).

Ramp-Up at Startup and Reconnection
When connecting the inverter, the maximum rate of change of the effective power can be limited by a rising ramp with a defined gradient. As soon as the effective power increase is influenced due to the available PV power or another control, the ramp is terminated.

Parameter	Range of values	Description
Ramp-Up at Startup and Reconnection	On	The effective power is limited at the Startup or a Reconnection with a rate of change of Ramp-Up at Startup and Reconnection Rate.
Ramp-Up at Startup and Reconnection	Off	The function is deactivated.
Ramp-Up at Startup and Reconnection Rate.	0.001 ‑ 100 [%/s]	Permitted rate of change of the effective power at Startup or Reconnection.

Ramp-Up/Down Irradiation
The Irradiation Ramp is a permanent limitation of the rate of change for the effective power. If the PV power changes rapidly due to passing clouds, the rate of change of the inverter output power is limited with the Ramp-Up Irradiation Rate or the Ramp-Down Irradiation Rate.

Parameter	Range of values	Description
Ramp-Up Irradiation	On	The effective power increase is limited with a rate of change of Ramp-Up Irradiation Rate.
Ramp-Up Irradiation	Off	The function is deactivated.
Ramp-Up Irradiation Rate	0.001 - 200 [%/s]	Permitted rate of change during power increase.
Ramp-Down Irradiation Note: This function only has an effect on inverters with storage.	On	The effective power reduction is limited with a rate of change of Ramp-Down Irradiation Rate.
	Off	The function is deactivated.
Ramp-Down Irradiation Rate	0.001 - 200 [%/s]	Permitted rate of change of effective power.

Example: Effective power limitation by Irradiation-Ramp-Up/Down, which was caused by a change in the available PV power.

Ramp-Up/Down Communication
This is a limitation of the effective power rate of change when changing external specifications for effective power. These can be, for example, power limitations via I/Os or Modbus commands. If smaller rates of change are specified via Modbus command, these are applied. Larger rates are limited by the parameter Ramp-Up Communication Rate or Ramp-Down Communication Rate.

Parameter	Range of values	Description
Ramp-Up Communication	On	The limitation of the rate of change (corresponding to Ramp-Up Communication Rate) in case of effective power increase due to an external specification is activated.
Ramp-Up Communication	Off	The function is deactivated.
Ramp-Up Communication Rate	0.001 ‑ 100 [%/s]	Permitted rate of change during power increase.
Ramp-Down Communication	On	The limitation of the rate of change (corresponding to Ramp-Down Communication Rate) in the event of effective power reduction due to an external specification is activated.
Ramp-Down Communication	Off	The function is deactivated.
Ramp-Down Communication Rate	0.001 ‑ 100 [%/s]	Permitted rate of change for power reduction.

Unintentional islanding
In the event of a grid failure or disconnection of a small part of the grid from the higher-level utility grid, it is possible under special conditions for local loads and inverters to establish unintentional islanding (stand-alone operation). If the generation and load (of both active and reactive power) are balanced, the AC voltage and frequency can remain within the allowable limits. In this case, the inverter (without additional islanding detection) will continue grid power feed operation, will not automatically shut down, and will supply power to the local loads. This is an unwanted condition. To prevent these situations, active or passive islanding detection methods can be used.

Active islanding detection
The inverter's active islanding detection function detects unwanted islanding situations, the inverter stops grid power feed operation, and disconnects from the AC grid at all poles.
The detection process is carried out using a mains frequency shift method (Active Frequency Drift): In the event of short-term mains frequency changes, the inverter feeds in an alternating current with a changed frequency (frequency shift). In the event of an interruption to the grid, the AC voltage will also change its frequency. There is a co-feedback effect, whereby the frequency is shifted so much that it exceeds or falls below the permissible limits. This causes the inverter to stop grid power feed operation.
In the case of three-phase inverters, the method is also able to detect islanding on any individual phases. This function is an active islanding detection method, since the inverter specifically changes its feed-in behavior during the detection process.

Parameter	Range of values	Standard value	Description
Unintentional Islanding Detection.	On		Active islanding detection is activated.
Unintentional Islanding Detection.	Off	Off	Active islanding detection is deactivated.
Quality Factor	0.1 ‑ 10.0	1.0	The higher this value, the stronger/more aggressive the frequency shift of the islanding detection. Higher values therefore result in shorter islanding detection times. However, values that are too high can also have a negative effect on the voltage quality.

In contrast, there are passive methods that detect islanding based only on the measurement of AC network variables. This group includes, for example, Rate of Change of Frequency (RoCoF) Protection.

Parameter	Range of values	Standard value	Description
Unintentional Islanding Detection.	On		Active islanding detection is activated.
Unintentional Islanding Detection.	Off	Off	Active islanding detection is deactivated.
Quality Factor	0.1 ‑ 10.0	1.0	The higher this value, the stronger/more aggressive the frequency shift of the islanding detection. Higher values therefore result in shorter islanding detection times. However, values that are too high can also have a negative effect on the voltage quality.

In contrast, there are passive methods that detect islanding based only on the measurement of AC network variables. This group includes, for example, Rate of Change of Frequency (RoCoF) Protection.

Isolation monitoring (Iso Monitoring)
The inverter performs an isolation measurement at the DC terminals of the PV generator before each connection (at least once a day). Isolation monitoring must be activated for both the isolation warning and the isolation error.

Isolation Warning
The measured value of the isolation monitoring is used for an isolation warning. Status code 1083 is displayed if the measured value falls below an adjustable limit value.

Isolation Error
The measured value of the isolation monitoring is also used for isolation error monitoring. If the measured isolation value is below the limit value Isolation Error Threshold, grid power feed operation is prevented and status code 1082 is displayed.

IMPORTANT!
For the Isolation Monitoring function, the parameters in the two menu sections described must be configured accordingly.

1The parameters below in the menu item Safety and grid regulations → Country setup → Safety → Isolation monitoring are used to configure the parameters for the isolation measurement:

Parameter	Range of values	Description
Iso Monitoring Mode	On	The function is activated.
	Off	The function is deactivated.
	Off (with Warning)	Isolation monitoring is deactivated and status code 1189 is permanently displayed on the user interface of the inverter.
Isolation Error Threshold	0.1 ‑ 10 MOhm	If the measured isolation value is lower than this value, grid power feed operation is prevented (if isolation monitoring is activated) and status code 1182 is displayed on the user interface of the inverter.

2The parameters below in the menu item Device configuration → Inverter → Iso warning are used to configure the parameters for the isolation warning:

Parameter	Range of values	Description
Iso Warning	On	The isolation warning is activated. If the isolation warning threshold is undershot, a warning occurs but not a shutdown.
Iso Warning	Off	The function is deactivated.
Isolation measurement mode	Precise	Isolation monitoring is performed with the highest accuracy and the measured insulation resistance is displayed on the user interface of the inverter.
Isolation measurement mode	Quick	Isolation monitoring is performed with lower accuracy, which shortens the duration of the isolation measurement and the isolation value is not displayed.
Isolation Warning Threshold	0.1 ‑ 10 MOhm	If this value is undershot, status code 1183 is displayed on the user interface of the inverter.

These parameters can be used to set the behavior of the arc detection at the DC terminals of the inverter. The DC arc fault protection function protects against arc faults and contact faults. Any faults that occur in the current and voltage curve are constantly evaluated and the current circuit is switched off if a contact fault is detected. This prevents overheating on defective contacts and possible fires.

Parameter	Range of values	Description
Arc Fault Detection (AFD)		For activating and deactivating the arc fault detection. The parameters Arc logging and Automatic reconnects are only considered with activated Arc Fault Detection (AFD).
	Off	Arcs are not detected.
	Off (with Warning)	Arcs are not detected and status code 1184 is permanently displayed on the user interface of the inverter.
	On	The arc detection is active.
Arc-Fault Circuit Interrupter (CI)		Describes the behavior in the event of a detected arc and simultaneously activates/deactivates the integrated self-test.
	Off	The detection of an arc does not cause the inverter to shut down and is not displayed on the user interface of the inverter.
	Off (with Warning)	The detection of an arc does not cause the inverter to shut down. The status code 1185 is permanently displayed on the user interface of the inverter.
	On	If an arc is detected, the inverter interrupts grid power feed operation and the status code 1006 is displayed on the user interface of the inverter. Depending on the configuration of the parameter Automatic Reconnects, the inverter will attempt to restart grid power feed operation after 5 minutes. Furthermore, an integrated self-test is active, which is executed at regular intervals. If this fails, the inverter stops grid power feed operation and status code 1009 is displayed.
Automatic Reconnects		If more arcs have been detected within 24 hours than are defined in Automatic Reconnects, the inverter will not make any further attempt to start grid power feed operation. The status code 1006 is displayed on the user interface of the inverter after each detection and must be acknowledged manually.
	Unlimited	The 24 hour counter is deactivated. The inverter restarts grid power feed operation 5 minutes after each arc detected.
	0 - No Reconnection	After an arc has been detected, no further attempt is made to start grid power feed operation and status code 1173 is displayed on the user interface of the inverter.
	1 ‑ 4	After a shutdown by an arc, 1, 2, 3, or 4 attempts are made within 24 hours to restart grid power feed operation. After this number of attempts, no further attempt is made to start grid power feed operation and status code 1173 is displayed on the user interface of the inverter.
Arc Logging		Enables or disables the recording of arc signatures. The data is uploaded to the cloud and used to continuously improve the interference immunity and fault tolerance of arc detection.
	Off	Arc signatures are not recorded.
	On	Arc signatures are recorded, uploaded to the cloud, and used to continuously improve the interference immunity and fault tolerance of arc detection.
Automatic Signal Recording		Activates or deactivates recording of the inverter's signal characteristics to continuously improve arc detection.
	Off	Recording is deactivated.
	On	Recording is activated. With a probability in accordance with the Recording Probability parameter, data is recorded and uploaded to the cloud every 10 minutes.
Recording Probability		If Automatic Signal Recording (ASR) is activated, the frequency for a recording can be set here.
	0	No signal characteristics are recorded.
	0.0 ‑ 1.0	Every 10 minutes, data is uploaded to the cloud with a frequency in accordance with the Recording Probability. Example: With a setting value of 0.1, data is uploaded on average every 100 minutes.
	1	Data is recorded every 10 minutes.

The inverter is equipped with a universal current-sensitive residual current monitoring unit (RCMU) in accordance with IEC 62109-2. This unit monitors residual currents from the PV module to the AC output of the inverter and disconnects the inverter from the grid in the event of unauthorized residual current.

Parameter	Range of values	Description
RCMU	Off	The protective function is deactivated.
	Off (with Warning)	The protective function is deactivated. The status code 1188 is permanently displayed on the user interface of the inverter.
	On	The protective function is activated.
Automatic Reconnects		If more fault currents have been detected within 24 hours than are defined in "Automatic Reconnects", the inverter will not make any further attempt to start grid power feed operation. The status code 1076 is displayed on the user interface of the inverter and must be acknowledged manually.
	0	No fault current above 300 mA is tolerated. After each detected fault current, grid power feed operation is interrupted and the status code must be acknowledged manually on the user interface of the inverter.
	1 ‑ 4	After a shutdown due to a fault current exceeding 300 mA, 1, 2, 3, or 4 attempts are made within 24 hours to restart grid power feed operation. After this number of attempts, no further attempt is made to start grid power feed operation and the status code must be acknowledged manually on the user interface of the inverter.
	Unlimited	The 24 hour counter is deactivated. The inverter restarts grid power feed operation after each detected fault current above 300 mA.

Devices for shutdown within the DC generator (e.g., in or on the module or within a string) can be controlled by the inverter. The condition for this is compatibility, especially with the communication of the inverter.

Parameter	Range of values	Description
Powerline Communication		Activates and deactivates DC powerline communication (PLC) on the inverter.
	PLC Off	DC powerline communication is deactivated on the inverter. There are no shutdown devices installed in the PV system, or if shutdown devices are installed in the PV system that are waiting for an enable signal, then this signal must come from another device (transmitter) (otherwise the system will not function).
	SunSpec PLC	The inverter communicates with DC powerline communication according to the SunSpec Rapid Shutdown Standard. Compatible shutdown devices must be used for the correct functioning of the PV system.

This chapter deals with the protection settings for overvoltage and undervoltage. Mains voltage limits are defined for this purpose. These depend on the country setup and can be adjusted as described below.

Each mains voltage limit is defined by:

an undervoltage with associated protection time, or
an overvoltage with associated protection time.

The protection time describes the duration for which the voltage may be outside the respective voltage limit value before the inverter switches off with an error message.
Three overvoltage and three undervoltage limit values can be used. The Inner Limits (U< for undervoltage; U>for overvoltage) refer to those limit values which are closer to the nominal voltage. The Middle Limits (U< for undervoltage; U>for overvoltage) have a greater distance to the nominal voltage. The greatest distance between the nominal voltage and the limit value is for the Outer Limits (U<< for undervoltage; U>> for overvoltage).
For expedient use of the Inner Limits and Outer Limits, the respective Inner Limit must be linked to a greater time than the Outer Limit. If the Middle Limits are also used, their time must be set between Inner Limit and Outer Limit; see example in the diagram.

Graphic illustrating the limits

IL	Inner limit - inner limit value
ML	Middle Limit - middle limit value
OL	Outer limit - outer limit value
(1)	Trip range
OV	Overvoltage
UV	Undervoltage
t_x	Protection time

These voltage limit values are not active in backup power mode. Under Device configuration → Inverter → Backup power, the voltage limits that apply in backup power mode can be configured.

Inner Limits

Parameter	Description
Undervoltage U<	Setting value for undervoltage protection U< in [V]
Undervoltage Time U<	Setting value of time for undervoltage protection U< in [s]
Overvoltage U>	Setting value for surge protection U> in [V]
Overvoltage Time U>	Setting value of time for surge protection U> in [s]

Middle Limits

Parameter	Description
Voltage Middle Limits	Activate/deactivate the middle voltage limit values On / Off
Undervoltage U<	Setting value for undervoltage protection U< in [V]
Undervoltage Time U<	Setting value of time for undervoltage protection U< in [s]
Overvoltage U>	Setting value for surge protection U> in [V]
Overvoltage Time U>	Setting value of time for surge protection U> in [s]

Outer Limits

Parameter	Description
Voltage Outer Limits	Activate/deactivate the outer voltage limit values On / Off
Undervoltage U<<	Setting value for undervoltage protection U<< in [V]
Undervoltage Time U<<	Setting value of time for undervoltage protection U<< in [s]
Overvoltage U>>	Setting value for surge protection U>> in [V]
Overvoltage Time U>>	Setting value of time for surge protection U>> in [s]

Long Time Average Limit
This function calculates a moving average voltage value over the set time and compares it with the set overvoltage protection value. If the overvoltage protection value is exceeded, a disconnect occurs.

Parameter	Description
Long Time Average Limit	Activate/deactivate the voltage average limit value On / Off / On at Smart Meter
Overvoltage U>	Setting value of the surge protection with average value formation U> in [V] ( Measurement at the feed-in point)
Overvoltage U> internal during „On at Smart Meter“ mode	Setting value of the surge protection with average value formation U> in [V] (Measurement on the Fronius Smart Meter)
Overvoltage Averaging Time U>	Time period over which the average value is calculated in [s]. (If 0 s is set, the check is not active)

Fast Overvoltage Disconnect
Fast overvoltage disconnect for voltage spikes that can respond within one period.

Parameter	Description
Fast Overvoltage Disconnect	Activate/deactivate fast RMS overvoltage disconnect (exceeding 135 % of rated voltage) On / Off
Fast Overvoltage Disconnect Time	Setting value of time for fast surge protection (peak value exceeded by 35 %) in [s]. This disconnect can be configured in the time range of microseconds.

Startup and Reconnection
Before the inverter is allowed to connect, the connection conditions for voltage and frequency must be fulfilled for a certain time.

A distinction is made between:

Startup: switching on the inverter during a normal startup process (e.g., at sunrise) and
Reconnection: the reconnection of the inverter after a grid fault (see table Grid faults) (e.g., if a fault occurs in the AC grid during the day which causes the inverter to disconnect).

Which limit values are used when checking the connection conditions depends on whether a grid fault has occurred and which Mode is defined. The Mode only influences the limit values and not the monitoring time. The monitoring time is determined by the parameters described in General / Startup and Reconnection. The monitoring time used depends on whether a Startup or Reconnection is taking place, and applies equally to frequency and voltage limits. After the grid monitoring has expired, the previously mentioned Interface Protection values are active. In backup power mode these Startup and Reconnection parameters are not active.

Parameter	Description
Mode	The following modes are available: Startup Values are used for Startup / Reconnection Values are used for Reconnection: In a normal startup process, the startup values are used as connection conditions. When reconnecting after a grid fault, the reconnection values are used as connection conditions. Startup Values are used for Startup and Reconnection: Regardless of the type of connection, the startup values are always used as connection conditions.
Reconnection Minimum Voltage	Lower value of the voltage for reconnection in [V]
Reconnection Maximum Voltage	Upper value of the voltage for reconnection in [V]
Startup Minimum Voltage	Lower value of the voltage for the normal start process in [V]
Startup Maximum Voltage	Upper value of the voltage for the normal start process in [V]
The following errors are defined by the inverter as grid errors for this functionality:

Name	Description	StateCode name	StateCode number
Overvoltage	Mains voltage exceeds an overvoltage limit (Inner, Middle, or Outer Limit Overvoltage).	AC voltage too high	1114
Undervoltage	Mains voltage falls below an undervoltage limit (Inner, Middle or Outer Limit Undervoltage).	AC voltage too low	1119
Overfrequency	Mains frequency exceeds an overfrequency limit (Inner, Outer or Alternative Limit Overfrequency).	AC frequency too high	1035
Underfrequency	Mains frequency falls below an underfrequency limit (Inner, Outer or Alternative Limit Underfrequency).	AC frequency too low	1037
Fast Overvoltage Disconnect	Triggering of the fast surge protection (> 135%).	Grid voltage too high (fast overvoltage cut-out)	1115, 1116
Long Time Average Overvoltage Limit	Mains voltage exceeds the long-term overvoltage limit (Long Time Average Limit).	Long-term mains voltage limit exceeded	1117
Unintentional Islanding Detection.	Unintentional islanding was detected.	Islanding detected	1004

Each mains voltage limit is defined by:

an undervoltage with associated protection time, or
an overvoltage with associated protection time.

Graphic illustrating the limits

IL	Inner limit - inner limit value
ML	Middle Limit - middle limit value
OL	Outer limit - outer limit value
(1)	Trip range
OV	Overvoltage
UV	Undervoltage
t_x	Protection time

These voltage limit values are not active in backup power mode. Under Device configuration → Inverter → Backup power, the voltage limits that apply in backup power mode can be configured.

Inner Limits

Parameter	Description
Undervoltage U<	Setting value for undervoltage protection U< in [V]
Undervoltage Time U<	Setting value of time for undervoltage protection U< in [s]
Overvoltage U>	Setting value for surge protection U> in [V]
Overvoltage Time U>	Setting value of time for surge protection U> in [s]

Middle Limits

Parameter	Description
Voltage Middle Limits	Activate/deactivate the middle voltage limit values On / Off
Undervoltage U<	Setting value for undervoltage protection U< in [V]
Undervoltage Time U<	Setting value of time for undervoltage protection U< in [s]
Overvoltage U>	Setting value for surge protection U> in [V]
Overvoltage Time U>	Setting value of time for surge protection U> in [s]

Outer Limits

Parameter	Description
Voltage Outer Limits	Activate/deactivate the outer voltage limit values On / Off
Undervoltage U<<	Setting value for undervoltage protection U<< in [V]
Undervoltage Time U<<	Setting value of time for undervoltage protection U<< in [s]
Overvoltage U>>	Setting value for surge protection U>> in [V]
Overvoltage Time U>>	Setting value of time for surge protection U>> in [s]

Parameter	Description
Long Time Average Limit	Activate/deactivate the voltage average limit value On / Off / On at Smart Meter
Overvoltage U>	Setting value of the surge protection with average value formation U> in [V] ( Measurement at the feed-in point)
Overvoltage U> internal during „On at Smart Meter“ mode	Setting value of the surge protection with average value formation U> in [V] (Measurement on the Fronius Smart Meter)
Overvoltage Averaging Time U>	Time period over which the average value is calculated in [s]. (If 0 s is set, the check is not active)

Fast Overvoltage Disconnect
Fast overvoltage disconnect for voltage spikes that can respond within one period.

Parameter	Description
Fast Overvoltage Disconnect	Activate/deactivate fast RMS overvoltage disconnect (exceeding 135 % of rated voltage) On / Off
Fast Overvoltage Disconnect Time	Setting value of time for fast surge protection (peak value exceeded by 35 %) in [s]. This disconnect can be configured in the time range of microseconds.

Startup and Reconnection
Before the inverter is allowed to connect, the connection conditions for voltage and frequency must be fulfilled for a certain time.

A distinction is made between:

Startup: switching on the inverter during a normal startup process (e.g., at sunrise) and
Reconnection: the reconnection of the inverter after a grid fault (see table Grid faults) (e.g., if a fault occurs in the AC grid during the day which causes the inverter to disconnect).

Parameter	Description
Mode	The following modes are available: Startup Values are used for Startup / Reconnection Values are used for Reconnection: In a normal startup process, the startup values are used as connection conditions. When reconnecting after a grid fault, the reconnection values are used as connection conditions. Startup Values are used for Startup and Reconnection: Regardless of the type of connection, the startup values are always used as connection conditions.
Reconnection Minimum Voltage	Lower value of the voltage for reconnection in [V]
Reconnection Maximum Voltage	Upper value of the voltage for reconnection in [V]
Startup Minimum Voltage	Lower value of the voltage for the normal start process in [V]
Startup Maximum Voltage	Upper value of the voltage for the normal start process in [V]
The following errors are defined by the inverter as grid errors for this functionality:

Name	Description	StateCode name	StateCode number
Overvoltage	Mains voltage exceeds an overvoltage limit (Inner, Middle, or Outer Limit Overvoltage).	AC voltage too high	1114
Undervoltage	Mains voltage falls below an undervoltage limit (Inner, Middle or Outer Limit Undervoltage).	AC voltage too low	1119
Overfrequency	Mains frequency exceeds an overfrequency limit (Inner, Outer or Alternative Limit Overfrequency).	AC frequency too high	1035
Underfrequency	Mains frequency falls below an underfrequency limit (Inner, Outer or Alternative Limit Underfrequency).	AC frequency too low	1037
Fast Overvoltage Disconnect	Triggering of the fast surge protection (> 135%).	Grid voltage too high (fast overvoltage cut-out)	1115, 1116
Long Time Average Overvoltage Limit	Mains voltage exceeds the long-term overvoltage limit (Long Time Average Limit).	Long-term mains voltage limit exceeded	1117
Unintentional Islanding Detection.	Unintentional islanding was detected.	Islanding detected	1004

This chapter covers the protection settings for overfrequencies and underfrequencies. Mains frequency limit values are defined for this purpose. These depend on the country setup and can be adjusted as described below.

Each frequency limit value is defined by:

an underfrequency with corresponding protection time, or
an overfrequency with corresponding protection time.

The protection time is the duration for which the frequency may be outside the respective frequency limit value before the inverter shuts down with an error message. Two overfrequency and two underfrequency limit values can be applied. The Inner Limits (f< for underfrequency; f> for overfrequency) refer to the limit values that are closer to the rated frequency than the Outer Limits (f<< for underfrequency; f>> for overfrequency). To use both ranges effectively, the Inner Limits must be assigned a longer time period than the Outer Limits.

Graphic explaining the limits

IL	Inner Limit - Inner limit value
OL	Outer Limit - Outer limit value
(1)	Trigger range
OF	Overfrequency
UF	Underfrequency

In backup power mode, the inverter itself determines the frequency and the frequency limit values are therefore not active.

Inner Limits

Parameter	Description
Underfrequency f<	Setting value for underfrequency protection f< in [Hz]
Underfrequency Time f<	Time setting value for underfrequency protection f< in [s]
Overfrequency f>	Setting value for overfrequency protection f> in [Hz]
Overfrequency Time f>	Time setting value for overfrequency protection f> in [s]

Outer Limits

Parameter	Description
Frequency Outer Limits	Activation / deactivation of the outer frequency limit values on / off
Underfrequency f<<	Setting value for underfrequency protection f<< in [Hz]
Underfrequency Time f<<	Time setting value for underfrequency protection f<< in [s]
Overfrequency f>>	Setting value for overfrequency protection f>> in [Hz]
Overfrequency Time f>>	Time setting value for overfrequency protection f>> in [s]

Alternative Limits
There is an additional second parameter set for the inner frequency limit values, which is only relevant for Italy. To activate the second parameter set, the alternative frequency limit value must be set to On on the user interface of the inverter and activated/deactivated via an external signal as follows:

Activation: http://<IP>/status/SetSignaleEsterno
Deactivation: http://<IP>/status/ClearSignaleEsterno

Each time the inverter is restarted, the Frequency Alternative Limit does not need to be set to On again, but the external activation signal must be sent again. If it is not sent, the inner frequency limit value will be used.

Parameter	Description
Frequency Alternative Limits	Activation / deactivation of alternative frequency limit values on / off
Underfrequency f<	Setting value for alternative underfrequency protection f< in [Hz]
Underfrequency Time f<	Time setting value for alternative underfrequency protection f< in [s]
Overfrequency f>	Setting value for alternative overfrequency protection f> in [Hz]
Overfrequency Time f>	Time setting value for alternative overfrequency protection f> in [s]

Startup and Reconnection
Before the inverter can be connected, the connection conditions for voltage and frequency must be met for a certain period of time.

A distinction is made between:

Startup: Connecting the inverter during a normal startup process (e.g., at sunrise); and
Reconnection: Reconnecting the inverter after a grid error (see Grid Error table) (e.g., if a fault occurs in the AC grid during the day that causes the inverter to shut down).

The limit values used to check the connection conditions depend on whether a grid error has occurred and which mode is defined. The mode only influences the limit values and not the monitoring time. The monitoring time is determined by the parameters described in General / Startup and Reconnection. The monitoring time used depends on whether a Startup or "Reconnection" is taking place and applies equally to frequency and voltage limit values. After grid monitoring has ended, the aforementioned "Interface Protection" values are active. In backup power mode, these "Startup and Reconnection" parameters are not active.

Parameter	Description
"Mode"	The following modes are available: Startup Values are used for Startup / Reconnection Values are used for Reconnection: During a normal startup process, the startup values are used as connection conditions. When reconnecting after a grid error, the reconnection values are used as connection conditions. Startup Values are used for Startup and Reconnection: Regardless of the type of connection, the startup values are always used as connection conditions. Startup Values are used for Reconnection: When reconnecting after a grid error, the startup values are used as connection conditions. During a normal startup process, Frequency Inner Limits f< and f> are used as connection conditions.
Startup Minimum Frequency	Lower value of the mains frequency for the normal startup process in [Hz]
Startup Maximum Frequency	Upper value of the mains frequency for the normal startup process in [Hz]
Reconnection Minimum Frequency	Lower value of the mains frequency for reconnection in [Hz]
Reconnection Maximum Frequency	Upper value of the mains frequency for reconnection in [Hz]
Tripping time for frequency limit violation	Tripping time when the frequency limit value is exceeded in [s]
The following faults are defined as grid errors by the inverter for this functionality:

Designation	Description	StateCode Name	StateCode Number
Overvoltage	Mains voltage exceeds an overvoltage limit (Inner, Middle, or Outer Limit Overvoltage).	AC voltage too high	1114
Undervoltage	Mains voltage falls below an undervoltage limit (Inner, Middle, or Outer Limit Undervoltage).	AC voltage too low	1119
Overfrequency	Mains frequency exceeds an overfrequency limit (Inner, Outer, or Alternative Limit Overfrequency).	AC frequency too high	1035
Underfrequency	Mains frequency falls below an underfrequency limit (Inner, Outer, or Alternative Limit Underfrequency).	AC frequency too low	1037
Fast Overvoltage Disconnect	Triggering of the fast surge protection device (> 135%).	Grid voltage too high (fast overvoltage cut-out)	1115, 1116
Long Time Average Overvoltage Limit	Mains voltage exceeds the long-term overvoltage limit (Long Time Average Limit).	Long-term mains voltage limit exceeded	1117
Unintentional Islanding Detection	Unintentional islanding has been detected.	Islanding detected	1004

Rate of Change of Frequency (RoCoF) Protection
This function is used to activate and adjust the RoCoF (Rate of Change of Frequency) detection and shutdown. If the frequency changes by more than a set value and lasts longer than the set time, the inverter will shut down. RoCoF detection is a passive islanding detection method.

IMPORTANT!
RoCoF detection is a protective function that specifically detects critical frequency changes and, if necessary, shuts down the inverter. It is not a function that can be used to carry out rapid frequency changes without shutdown (RoCoF robustness). RoCoF robustness is an intrinsic capability of an inverter and cannot be activated or deactivated.

Parameter	Value Range	Default Value	Description
Rate of Change of Frequency (RoCoF) Protection	On / off	Off	Activation and deactivation of the RoCoF protection.
RoCoF Limit	0.05 - 99 Hz/s	2.5 Hz/s	Limit value for the frequency change that causes a shutdown when ROCOF detection is activated.
RoCoF Detection Measurement Window Time	0.04 - 10 s	0.5 s	Measurement window length for calculating the RoCoF value
RoCoF Trip Time	0.05 - 16 s	0.3 s	Setting value for the ROCOF protection shutdown time.

Export Limit Protection (P_AV,E) monitors compliance with the feed-in limit agreed with the utility. If the limit values have been exceeded or the control is too slow, all inverters in the system are switched off.

P_{mom, grid}	measured, current power of feeding in
P_inst	Total installed AC generator power (P_inst) - installed active power of all operated producers in the system
P_AV,E	Max. feed-in power (P_AV,E) - agreed feed-in limit

P_AV,E protection setting values
Parameter	Explanation	Switch-off value*
Time P>>>	x-coordinate point 1	1.6 s
Factor P>>>	y-coordinate point 1	90%
Time P>>	x-coordinate point 2	4 s
Factor P>>	y-coordinate point 2	15%
Time P>	x-coordinate point 3	11 s
Factor P>	y-coordinate point 3	5%

*The above example values apply to Germany.

DC injection means the injection of an AC current into the public grid that is unintentionally contaminated with a DC component. This DC component causes a shift of the pure AC current on the Y-axis (offset).
Due to the way the inverter works, no DC injection takes place in normal operation. However, in order to be protected against faults or inaccuracies, many connection rules require monitoring of the DC injection and shutdown if limit values are exceeded.
Inner and outer limits can be defined for the limit values. Inner limits have tighter limits and longer protection times by default, outer limits have broader limits and shorter protection times, so that shutdown occurs more quickly with higher DC components. For both limit values there is a protection time which defines the maximum overshoot duration.

Inner Limit

Parameter	Range of values	Description
Mode	Off	Monitoring of the inner limit is deactivated.
	Absolute	DC component monitoring with an absolute current limit in [A].
	Relative	DC component monitoring with a relative current limit expressed as a percentage [%] of the nominal current of the inverter.
DC Current Absolute Value	0.0 A ‑ 10.0 A	Absolute DC current limit in [A] - If the DC component of the injected AC current exceeds this limit for the duration defined with DC Injection Time, grid power feed operation is interrupted with status code 1052. This limit only applies to the Absolute mode.
DC Current Relative Value	0.0 % ‑ 10.0 %	Relative DC current limit expressed as a percentage of the nominal current of the inverter - If the relative DC component of the injected AC current exceeds this limit for the duration defined with DC Injection Time, grid power feed operation is interrupted with status code 1052. This limit only applies to the Relative mode.
DC Injection Time	0.0 s ‑ 10.0 s	Protection time for the inner limit - Shutdown occurs after the respective limit value has been exceeded for this time.

Outer Limit

Parameter	Range of values	Description
Mode	Off	Monitoring of the outer limit is deactivated.
	Absolute	DC component monitoring with an absolute current limit in [A].
	Relative	DC component monitoring with a relative current limit expressed as a percentage [%] of the nominal current of the inverter.
DC Current Absolute Value	0.0 A ‑ 10.0 A	Absolute DC current limit in [A] - If the DC component of the injected AC current exceeds this limit for the duration defined with DC Injection Time, grid power feed operation is interrupted with status code 1052. This limit only applies to the Absolute mode.
DC Current Relative Value	0.0 % ‑ 10.0 %	Relative DC current limit expressed as a percentage of the nominal current of the inverter - If the relative DC component of the injected AC current exceeds this limit for the duration defined with DC Injection Time, grid power feed operation is interrupted with status code 1052. This limit only applies to the Relative mode.
DC Injection Time	0.0 s ‑ 10.0 s	Protection time for the outer limit - Shutdown occurs after the respective limit value has been exceeded for this time.

In the event of faults in the grid, there is a risk of a large number of generation plants being shut down unintentionally and thus a risk of network collapse. Mains voltage disturbances (Voltage Fault, Gridvoltage-Disturbance) are short-term voltage dips or surges in the grid. These voltage changes go beyond the normal range of the operating voltage (e.g., nominal voltage +/- 10 %). However, the duration of the voltage changes is short, so that the normal operating voltage is reached again before the system is shut down (due to Interface Protection). Voltage fault ride through means that the inverter can ride through such a mains voltage fault without shutting down prematurely. If the shutdown conditions of the protection settings (Grid and system protection or Interface Protection) are reached (time and value), the inverter always shuts down, thus terminating VFRT operation. The requirements for the exact behavior of the inverters during the fault depend on the respective grid connection rules. The following parameters determine this behavior.

Classification into regions
The voltage fault detection of the inverter detects severe or rapid mains voltage fluctuations and classifies them into so-called regions according to the level of the fault voltage (voltage level during the fault). Each region is assigned a specific mains voltage value range. Three individual regions (R1, R2, R3) can be configured. Each individual region has an adjustable detection threshold and several parameters that determine the behavior of the inverter within that region. The detection limit is a relative voltage level and is specified as a percentage of the AC nominal voltage. A value above 100 % means that the associated region describes an overvoltage disturbance (High Voltage Ride Through, HVRT). A value less than 100 % means that the associated region describes an undervoltage fault (Low Voltage Ride Through, LVRT). Figure 1 shows an example of a typical arrangement of the three regions (shown here with horizontal bars) by selective choice of detection thresholds: R1 threshold 110 %, R2 threshold 90 %, R3 threshold 40 %. The voltage range between the limits of Region1 and Region2 (white bar) comprises the voltage range for normal operation (here: 90 to 110 % of the nominal voltage). Region 1 comprises overvoltage disturbances, Region 2 consists of slight undervoltage disturbances (from 90 to 40 %). Region 3 consists of severe undervoltage disturbances (below 40 %).

Division of the grid voltage range into three fault regions by selecting the detection thresholds.

IMPORTANT!
The length of the bars represents trip times for overvoltage and undervoltage detection of the Interface Protection function group. This has no significance for the VFRT functionality.

Regions R1 to R3 must have descending values of detection thresholds:

The R1 threshold must be higher than the R2 threshold, and so on.
The use of identical thresholds for multiple regions is prohibited.
Using the threshold value 0 % is allowed.

To deactivate a specific region, its threshold can be used:
An HV region (R1) is deactivated by adjusting the threshold to 200 %. An unused LV region (usually R3) is deactivated by adjusting the threshold to 0 %.

General VFRT settings
The following setting values apply equally to all regions.

Parameter	Value range	Standard value	Description
Mode	On		VFRT function is active according to the set parameter values.
Mode	Off	Off	If no special behavior is required during grid disturbances, the inverter will behave according to the default values in this table with this setting. Any parameter settings made are ignored.
Reactive Current Limit for Overexcited Operation.	0 ‑ 110 [% IacNominal]	100 %	Limitation of the reactive current during a mains voltage fault and overexcited operation - as a percentage of the nominal current l_N. This parameter is only effective for the current inrush mode Active Asymmetric Current.
Reactive Current Limit for Underexcited Operation.	0 ‑ 110 [% IacNominal]	100 %	Limitation of the reactive current during a mains voltage fault and underexcited operation - as a percentage of the nominal current l_N. This parameter is only effective for the current inrush mode Active Asymmetric Current.
Sudden Voltage Change Detection	On		The detection of sudden voltage changes within the normal voltage range is active. So-called sudden voltage changes do not usually violate static voltage limits, but are indicators of network disturbances.
Sudden Voltage Change Detection	Off	Off	No detection of sudden voltage changes within the normal voltage range.
Insensitivity Range	0 ‑ 100 [% Uac 1s‑Avg]	5 %	Limit value that must be exceeded by a sudden change in voltage (change in the positive sequence voltage or negative sequence voltage) for a mains voltage fault to be detected. Reference value for the calculation of this limit value is the moving average value of the mains voltage over 1 second (1s‑Avg).
Deactivation Time	0 ‑ 100 [s]	5 s	Time duration of grid fault handling for sudden voltage changes. After this time has elapsed, the grid fault handling is automatically terminated if no static voltage limits (see parameter Threshold Static under Region 1, 2, 3) have been violated.

Region 1
These setting values define how the inverter behaves within Region 1. The choice of setting has no effect on regions 2 and 3.

Parameter	Value range	Standard value	Description
Static Threshold	0 ‑ 200 [% UacNominal]	125 %	Static voltage threshold (in % of nominal voltage) that must be exceeded or fallen below to activate VFRT Region 1 and its associated current inrush mode. > 100 % ... Region 1 is used as the HVRT region. < 100 % ... Region 1 is used as the LVRT region. Setting condition: Threshold R1 > Threshold R2 > Threshold R3 Default value 125 % means that the inverter is in normal current feed-in operation up to 125 % of the nominal voltage. VFRT becomes active above 125 % with the selected current inrush mode (default mode for Region 1: Zero Current).
Static Detection Mode			Voltage system used for static threshold detection of VFRT Region 1. For three-phase devices, the minimum value (for LVRT regions) or the maximum value (for HVRT regions) from the individual voltages is used in each case.
	L-N Voltage	L-N Voltage	The phase-to-neutral (line-to-neutral) voltage system is used for static threshold detection of VFRT Region 1.
	L-L Voltage		The phase-to-phase (line-to-line) voltage system is used for static threshold detection of VFRT Region 1.
	L-L and L-N Voltage		Both voltage systems (line-to-neutral and line-to-line) are used for static threshold detection of VFRT Region 1.
Current Calc Mode			Current inrush mode for Region 1. This parameter defines the type of current feed during a Region 1 voltage fault.
	Passive		The pre-fault behavior is maintained as far as possible during the fault.
	Zero Current	Zero Current	The alternating current is adjusted to zero. There is no effective or reactive power feed-in during the fault.
	Active Symmetric Current		A symmetrical reactive current (positive-sequence system reactive current) is fed into the grid. The additional reactive current value results from the k-factor Positive Sequence multiplied by the amount of the voltage dip. No active current is fed in.
	Active Asymmetric Current		An additional reactive current is fed into the grid. At the same time, active current is fed in (whereby the reactive current has priority). The additional reactive current value results from the k-factors multiplied by the voltage dip value. If the k-factor Negative Sequence is set to 0, the feed is symmetrical. Otherwise, asymmetrical faults are responded to with an asymmetrical current infeed.
k-factor Positive Sequence	0 ‑ 10	2.0	Multiplication factor (k-factor) for the positive-sequence system reactive current in Region 1. Only applied with current inrush mode Active Symmetric Current and Active Asymmetric Current.
k-factor Negative Sequence	0 ‑ 10	2.0	Multiplication factor (k-factor) for the negative-sequence system reactive current in Region 1. Only applied with current inrush mode Active Asymmetric Current. If an asymmetrical feed is required, this is usually set to the same value as k-factor Positive Sequence. If a symmetrical supply is required, this is set to 0.

Region 2
These setting values define how the inverter behaves within Region 2. The choice of setting has no effect on regions 1 and 3.

Parameter	Value range	Standard value	Description
Static Threshold	0 ‑ 200 [% UacNominal]	40 %	Static voltage threshold (in % of nominal voltage) that must be exceeded or fallen below to activate VFRT Region 2 and its associated current inrush mode. > 100 % ... Region 2 is used as the HVRT region. < 100 % ... Region 2 is used as the LVRT region. Setting condition: Threshold R1 > Threshold R2 > Threshold R3 Default value 40 % means that the inverter is in normal current feed-in operation up to 40 % of the nominal voltage. VFRT becomes active above 40 % with the selected current inrush mode (default mode for Region 2: Zero Current).
Static Detection Mode			Voltage system used for static threshold detection of VFRT Region 2. For three-phase devices, the minimum value (for LVRT regions) or the maximum value (for HVRT regions) from the individual voltages is used in each case.
	L-N Voltage	L-N Voltage	The phase-to-neutral (line-to-neutral) voltage system is used for static threshold detection of VFRT Region 2.
	L-L Voltage		The phase-to-phase (line-to-line) voltage system is used for static threshold detection of VFRT Region 2.
	L-L and L-N Voltage		Both voltage systems (line-to-neutral and line-to-line) are used for static threshold detection of VFRT Region 2.
Current Calc Mode			Current inrush mode for Region 2. This parameter defines the type of current feed during a Region 2 voltage fault.
	Passive		The pre-fault active current and reactive current is maintained for as long as the fault persists.
	Zero Current	Zero Current	The alternating current is adjusted to zero. There is no effective or reactive power feed-in during the fault.
	Active Symmetric Current		A symmetrical reactive current (positive-sequence system reactive current) is fed into the grid. The additional reactive current value results from the k-factor Positive Sequence multiplied by the amount of the voltage dip. No active current is fed in.
	Active Asymmetric Current		An additional reactive current is fed into the grid. At the same time, active current is fed in (whereby the reactive current has priority). The additional reactive current value results from the k-factors multiplied by the voltage dip value. If the k-factor Negative Sequence is set to 0, the feed is symmetrical. Otherwise, asymmetrical faults are responded to with an asymmetrical current infeed.
k-factor Positive Sequence	0 ‑ 10	2.0	Multiplication factor (k-factor) for the positive-sequence system reactive current in Region 2. Only applied with current inrush mode Active Symmetric Current and Active Asymmetric Current.
k-factor Negative Sequence	0 ‑ 10	2.0	Multiplication factor (k-factor) for the negative-sequence system reactive current in Region 2. Only applied with current inrush mode Active Asymmetric Current. If an asymmetrical feed is required, this is usually set to the same value as k-factor Positive Sequence. If a symmetrical supply is required, this is set to 0.

Region 3
These setting values define how the inverter behaves within Region 3. The choice of setting has no effect on regions 1 and 2.

Parameter	Value range	Standard value	Description
Static Threshold	0 ‑ 200 [% UacNominal]	0 %	Static voltage threshold (in % of nominal voltage) that must be exceeded or fallen below to activate VFRT Region 3 and its associated current inrush mode. > 100 % ... Region 3 is used as the HVRT region. < 100 % ... Region 3 is used as the LVRT region. Setting condition: Threshold R1 > Threshold R2 > Threshold R3 Default value 0 % means that Region 3 is disabled/inactive.
Static Detection Mode			Voltage system used for static threshold detection of VFRT Region 3. For three-phase devices, the minimum value (for LVRT regions) or the maximum value (for HVRT regions) from the individual voltages is used in each case.
	L-N Voltage	L-N Voltage	The phase-to-neutral (line-to-neutral) voltage system is used for static threshold detection of VFRT Region 3.
	L-L Voltage		The phase-to-phase (line-to-line) voltage system is used for static threshold detection of VFRT Region 3.
	L-L and L-N Voltage		Both voltage systems (line-to-neutral and line-to-line) are used for static threshold detection of VFRT Region 3.
Current Calc Mode			Current inrush mode for Region 3. This parameter defines the type of current feed during a Region 3 voltage fault.
	Passive		The pre-fault active current and reactive current is maintained for as long as the fault persists.
	Zero Current	Zero Current	The alternating current is adjusted to zero. There is no effective or reactive power feed-in during the fault.
	Active Symmetric Current		A symmetrical reactive current (positive-sequence system reactive current) is fed into the grid. The additional reactive current value results from the k-factor Positive Sequence multiplied by the amount of the voltage dip. No active current is fed in.
	Active Asymmetric Current		An additional reactive current is fed into the grid. At the same time, active current is fed in (whereby the reactive current has priority). The additional reactive current value results from the k-factors multiplied by the voltage dip value. If the k-factor Negative Sequence is set to 0, the feed is symmetrical. Otherwise, asymmetrical faults are responded to with an asymmetrical current infeed.
k-factor Positive Sequence	0 ‑ 10	2.0	Multiplication factor (k-factor) for the positive-sequence system reactive current in Region 3. Only applied with current inrush mode Active Symmetric Current and Active Asymmetric Current.
k-factor Negative Sequence	0 ‑ 10	2.0	Multiplication factor (k-factor) for the negative-sequence system reactive current in Region 3. Only applied with current inrush mode Active Asymmetric Current. If an asymmetrical feed is required, this is usually set to the same value as k-factor Positive Sequence. If a symmetrical supply is required, this is set to 0.

Division of the grid voltage range into three fault regions by selecting the detection thresholds.

IMPORTANT!
The length of the bars represents trip times for overvoltage and undervoltage detection of the Interface Protection function group. This has no significance for the VFRT functionality.

Regions R1 to R3 must have descending values of detection thresholds:

The R1 threshold must be higher than the R2 threshold, and so on.
The use of identical thresholds for multiple regions is prohibited.
Using the threshold value 0 % is allowed.

General VFRT settings
The following setting values apply equally to all regions.

Parameter	Value range	Standard value	Description
Mode	On		VFRT function is active according to the set parameter values.
Mode	Off	Off	If no special behavior is required during grid disturbances, the inverter will behave according to the default values in this table with this setting. Any parameter settings made are ignored.
Reactive Current Limit for Overexcited Operation.	0 ‑ 110 [% IacNominal]	100 %	Limitation of the reactive current during a mains voltage fault and overexcited operation - as a percentage of the nominal current l_N. This parameter is only effective for the current inrush mode Active Asymmetric Current.
Reactive Current Limit for Underexcited Operation.	0 ‑ 110 [% IacNominal]	100 %	Limitation of the reactive current during a mains voltage fault and underexcited operation - as a percentage of the nominal current l_N. This parameter is only effective for the current inrush mode Active Asymmetric Current.
Sudden Voltage Change Detection	On		The detection of sudden voltage changes within the normal voltage range is active. So-called sudden voltage changes do not usually violate static voltage limits, but are indicators of network disturbances.
Sudden Voltage Change Detection	Off	Off	No detection of sudden voltage changes within the normal voltage range.
Insensitivity Range	0 ‑ 100 [% Uac 1s‑Avg]	5 %	Limit value that must be exceeded by a sudden change in voltage (change in the positive sequence voltage or negative sequence voltage) for a mains voltage fault to be detected. Reference value for the calculation of this limit value is the moving average value of the mains voltage over 1 second (1s‑Avg).
Deactivation Time	0 ‑ 100 [s]	5 s	Time duration of grid fault handling for sudden voltage changes. After this time has elapsed, the grid fault handling is automatically terminated if no static voltage limits (see parameter Threshold Static under Region 1, 2, 3) have been violated.

Region 1
These setting values define how the inverter behaves within Region 1. The choice of setting has no effect on regions 2 and 3.

Parameter	Value range	Standard value	Description
Static Threshold	0 ‑ 200 [% UacNominal]	125 %	Static voltage threshold (in % of nominal voltage) that must be exceeded or fallen below to activate VFRT Region 1 and its associated current inrush mode. > 100 % ... Region 1 is used as the HVRT region. < 100 % ... Region 1 is used as the LVRT region. Setting condition: Threshold R1 > Threshold R2 > Threshold R3 Default value 125 % means that the inverter is in normal current feed-in operation up to 125 % of the nominal voltage. VFRT becomes active above 125 % with the selected current inrush mode (default mode for Region 1: Zero Current).
Static Detection Mode			Voltage system used for static threshold detection of VFRT Region 1. For three-phase devices, the minimum value (for LVRT regions) or the maximum value (for HVRT regions) from the individual voltages is used in each case.
	L-N Voltage	L-N Voltage	The phase-to-neutral (line-to-neutral) voltage system is used for static threshold detection of VFRT Region 1.
	L-L Voltage		The phase-to-phase (line-to-line) voltage system is used for static threshold detection of VFRT Region 1.
	L-L and L-N Voltage		Both voltage systems (line-to-neutral and line-to-line) are used for static threshold detection of VFRT Region 1.
Current Calc Mode			Current inrush mode for Region 1. This parameter defines the type of current feed during a Region 1 voltage fault.
	Passive		The pre-fault behavior is maintained as far as possible during the fault.
	Zero Current	Zero Current	The alternating current is adjusted to zero. There is no effective or reactive power feed-in during the fault.
	Active Symmetric Current		A symmetrical reactive current (positive-sequence system reactive current) is fed into the grid. The additional reactive current value results from the k-factor Positive Sequence multiplied by the amount of the voltage dip. No active current is fed in.
	Active Asymmetric Current		An additional reactive current is fed into the grid. At the same time, active current is fed in (whereby the reactive current has priority). The additional reactive current value results from the k-factors multiplied by the voltage dip value. If the k-factor Negative Sequence is set to 0, the feed is symmetrical. Otherwise, asymmetrical faults are responded to with an asymmetrical current infeed.
k-factor Positive Sequence	0 ‑ 10	2.0	Multiplication factor (k-factor) for the positive-sequence system reactive current in Region 1. Only applied with current inrush mode Active Symmetric Current and Active Asymmetric Current.
k-factor Negative Sequence	0 ‑ 10	2.0	Multiplication factor (k-factor) for the negative-sequence system reactive current in Region 1. Only applied with current inrush mode Active Asymmetric Current. If an asymmetrical feed is required, this is usually set to the same value as k-factor Positive Sequence. If a symmetrical supply is required, this is set to 0.

Region 2
These setting values define how the inverter behaves within Region 2. The choice of setting has no effect on regions 1 and 3.

Parameter	Value range	Standard value	Description
Static Threshold	0 ‑ 200 [% UacNominal]	40 %	Static voltage threshold (in % of nominal voltage) that must be exceeded or fallen below to activate VFRT Region 2 and its associated current inrush mode. > 100 % ... Region 2 is used as the HVRT region. < 100 % ... Region 2 is used as the LVRT region. Setting condition: Threshold R1 > Threshold R2 > Threshold R3 Default value 40 % means that the inverter is in normal current feed-in operation up to 40 % of the nominal voltage. VFRT becomes active above 40 % with the selected current inrush mode (default mode for Region 2: Zero Current).
Static Detection Mode			Voltage system used for static threshold detection of VFRT Region 2. For three-phase devices, the minimum value (for LVRT regions) or the maximum value (for HVRT regions) from the individual voltages is used in each case.
	L-N Voltage	L-N Voltage	The phase-to-neutral (line-to-neutral) voltage system is used for static threshold detection of VFRT Region 2.
	L-L Voltage		The phase-to-phase (line-to-line) voltage system is used for static threshold detection of VFRT Region 2.
	L-L and L-N Voltage		Both voltage systems (line-to-neutral and line-to-line) are used for static threshold detection of VFRT Region 2.
Current Calc Mode			Current inrush mode for Region 2. This parameter defines the type of current feed during a Region 2 voltage fault.
	Passive		The pre-fault active current and reactive current is maintained for as long as the fault persists.
	Zero Current	Zero Current	The alternating current is adjusted to zero. There is no effective or reactive power feed-in during the fault.
	Active Symmetric Current		A symmetrical reactive current (positive-sequence system reactive current) is fed into the grid. The additional reactive current value results from the k-factor Positive Sequence multiplied by the amount of the voltage dip. No active current is fed in.
	Active Asymmetric Current		An additional reactive current is fed into the grid. At the same time, active current is fed in (whereby the reactive current has priority). The additional reactive current value results from the k-factors multiplied by the voltage dip value. If the k-factor Negative Sequence is set to 0, the feed is symmetrical. Otherwise, asymmetrical faults are responded to with an asymmetrical current infeed.
k-factor Positive Sequence	0 ‑ 10	2.0	Multiplication factor (k-factor) for the positive-sequence system reactive current in Region 2. Only applied with current inrush mode Active Symmetric Current and Active Asymmetric Current.
k-factor Negative Sequence	0 ‑ 10	2.0	Multiplication factor (k-factor) for the negative-sequence system reactive current in Region 2. Only applied with current inrush mode Active Asymmetric Current. If an asymmetrical feed is required, this is usually set to the same value as k-factor Positive Sequence. If a symmetrical supply is required, this is set to 0.

Region 3
These setting values define how the inverter behaves within Region 3. The choice of setting has no effect on regions 1 and 2.

Parameter	Value range	Standard value	Description
Static Threshold	0 ‑ 200 [% UacNominal]	0 %	Static voltage threshold (in % of nominal voltage) that must be exceeded or fallen below to activate VFRT Region 3 and its associated current inrush mode. > 100 % ... Region 3 is used as the HVRT region. < 100 % ... Region 3 is used as the LVRT region. Setting condition: Threshold R1 > Threshold R2 > Threshold R3 Default value 0 % means that Region 3 is disabled/inactive.
Static Detection Mode			Voltage system used for static threshold detection of VFRT Region 3. For three-phase devices, the minimum value (for LVRT regions) or the maximum value (for HVRT regions) from the individual voltages is used in each case.
	L-N Voltage	L-N Voltage	The phase-to-neutral (line-to-neutral) voltage system is used for static threshold detection of VFRT Region 3.
	L-L Voltage		The phase-to-phase (line-to-line) voltage system is used for static threshold detection of VFRT Region 3.
	L-L and L-N Voltage		Both voltage systems (line-to-neutral and line-to-line) are used for static threshold detection of VFRT Region 3.
Current Calc Mode			Current inrush mode for Region 3. This parameter defines the type of current feed during a Region 3 voltage fault.
	Passive		The pre-fault active current and reactive current is maintained for as long as the fault persists.
	Zero Current	Zero Current	The alternating current is adjusted to zero. There is no effective or reactive power feed-in during the fault.
	Active Symmetric Current		A symmetrical reactive current (positive-sequence system reactive current) is fed into the grid. The additional reactive current value results from the k-factor Positive Sequence multiplied by the amount of the voltage dip. No active current is fed in.
	Active Asymmetric Current		An additional reactive current is fed into the grid. At the same time, active current is fed in (whereby the reactive current has priority). The additional reactive current value results from the k-factors multiplied by the voltage dip value. If the k-factor Negative Sequence is set to 0, the feed is symmetrical. Otherwise, asymmetrical faults are responded to with an asymmetrical current infeed.
k-factor Positive Sequence	0 ‑ 10	2.0	Multiplication factor (k-factor) for the positive-sequence system reactive current in Region 3. Only applied with current inrush mode Active Symmetric Current and Active Asymmetric Current.
k-factor Negative Sequence	0 ‑ 10	2.0	Multiplication factor (k-factor) for the negative-sequence system reactive current in Region 3. Only applied with current inrush mode Active Asymmetric Current. If an asymmetrical feed is required, this is usually set to the same value as k-factor Positive Sequence. If a symmetrical supply is required, this is set to 0.

Voltage-dependent Power Control
or also called Volt/Watt function or P(U) function, causes a change in effective power depending on the mains voltage. By reducing the effective power at high mains voltage (or increasing the effective power at low mains voltage), an unintentional switch-off of the inverter due to the overvoltage or undervoltage limits can be avoided. This makes the yield losses less than they would be if the inverter was switched off.

When the function is activated and the specified mains voltage limit value is exceeded, the effective power

is reduced according to a defined gradient if the mains voltage is too high (see example System without storage - red characteristic curve)
is increased according to a defined gradient if the mains voltage is too low (only possible with hybrid inverters, see example System with storage - green characteristic curve).

In the case of a hybrid inverter with active grid support activated (Active Grid Support), additional scenarios arise:

If the output power has already been reduced to 0 W when the voltage is too high and the voltage continues to rise, additional energy can be taken from the national grid (the battery is thus charged, see System with storage and active grid support enabled - blue characteristic curve in the lower Power Input area).
If the charging power (drawn from the national grid) has been reduced to 0 W when the voltage is too low and the voltage continues to drop, additional energy can be drawn from the battery to increase the output power (see example System with storage and active grid support enabled - blue characteristic curve in the upper Power Output area).

Examples of active grid support:

System without storage
(graph - red characteristic curve)

Description of the parameter

Mode: On (without Hysteresis)
No battery in the system
Active Grid Support: Off
Calculation Mode: P_max = P_m‑P_n(k*df)

(1)	Momentary effective power when the Activation Threshold Overvoltage is reached: 50 % of P_n (equipment - nominal output)
(2)	Activation Threshold Overvoltage: 250 V
(3)	Gradient Overvoltage: 7.5 %/V

System with storage and active grid support disabled
(graphic - green characteristic curve)

Description of the parameter

Mode: On (without Hysteresis)
Battery is active
Active Grid Support: Off
Calculation Mode: P_max = P_m‑P_n(k*df)

(1) (4)	Momentary effective power when the respective Activation Threshold is reached: 50 % of P_n (equipment - nominal output)
(2)	Activation Threshold Overvoltage: 250 V
(3)	Gradient Overvoltage: 7.5 %/V
(5)	Activation Threshold Undervoltage: 210 V
(6)	Gradient Undervoltage: 7.5 %/V

System with storage and active grid support enabled
(graphic - blue characteristic curve)

Description of the parameter

Mode: On (without Hysteresis)
Battery is active
Active Grid Support: On
Calculation Mode: P_max = P_m‑P_n(k*df)

(1) (4)	Momentary effective power when the respective Activation Threshold is reached: 50 % of P_n (equipment - nominal output)
(2)	Activation Threshold Overvoltage: 250 V
(3)	Gradient Overvoltage: 7.5 %/V
(5)	Activation Threshold Undervoltage: 210 V
(6)	Gradient Undervoltage: 7.5 %/V

General power curve depending on mains voltage.

SOC (State Of Charge) limits can be set for active grid support with battery. If a limit is reached, the battery is no longer used for active grid support. These can be found under Battery SoC Limitation for Grid Support:

Battery SoC Lower Limit - The battery will not be further discharged when the lower limit is reached.
Battery SoC Upper Limit - The battery will not be further charged when the upper limit is reached.

Parameter	Value range	Description	Availability
Mode	Off	The function is deactivated.
Mode	On (without Hysteresis)	The function is activated.
Activation Threshold Overvoltage	208 ‑ 311 [V]	Mains voltage limit value above which the power reduction takes place.
Gradient Overvoltage	0.01 ‑ 100 [%/V]	Gradient by which the effective power is reduced. Example - conversion from static to gradient: Static s = 4 % → Gradient k = 1/(0.04*230 V) = 10.9 %/V
Calculation Mode	P_max = P_m-P_m(kdV) P_max = P_n-P_n(kdV) P_max = P_m-P_n(k*dV)	Indicates the reference power for calculating the power limit in the event of overvoltage or undervoltage. Reference power: P_m → Momentary power when the mains voltage limit value is exceeded. P_n → Nominal output of the device.
Active Grid Support	Off	Deactivates extended active grid support for devices with a battery.	Has no influence on the following setups: AUS Region A 2020 AUS Region B 2020 AUS Region C 2020 NZS 2020
Active Grid Support	On	Activates extended active grid support for devices with a battery.
Activation Threshold Undervoltage	0 ‑ 311 [V]	Mains voltage limit value above which the power increase takes place.
Gradient Undervoltage	0 ‑ 100 [%/V]	Gradient by which the effective power increases. Example - conversion from static to gradient: Static s = 4 % → Gradient k = 1/(0.04*230 V) = 10.9 %/V
Time Constant (τ)	0 ‑ 600 [s]	Time constant (1 Tau) in seconds [s]. Whenever the set value is changed, this new set value is not triggered abruptly, but smoothly in accordance with a PT1 response. The time constant describes how quickly the new set value is reached. (After three time constants the final value 95 % is reached)
Stop Voltage at Overvoltage	0 ‑ 311 [V]	Mains voltage limit value up to which the power reduction takes place. The gradient is automatically calculated from the parameters Activation Threshold Overvoltage and Power at Stop Voltage at Overvoltage. The parameters Gradient Overvoltage and Calculation Mode have no function.	Used exclusively in the following setups: AUS Region A 2020 AUS Region B 2020 AUS Region C 2020 NZS 2020
Power at Stop Voltage - Overvoltage	0 ‑ 100 [%]	Reference power when the set mains voltage limit value is reached.

Example: Setups AUS/NSZ 2020

Description of the parameter

Mode: On (without hysteresis)

(1)	Activation Threshold Overvoltage: 250 V
(2)	Stop at Voltage at Overvoltage: 260 V
(3)	Power at Stop Voltage - Overvoltage: 20 %

Power curve when Activation Threshold Overvoltage is exceeded.

Parameter	Value range	Description	Availability
Stop Voltage at Undervoltage	200 ‑ 311 [V]	Mains voltage limit value up to which the charging power of the battery is reduced. The gradient is calculated automatically from the parameters Activation Threshold Undervoltage and Power at Stop Voltage at Undervoltage. The parameters Gradient Undervoltage and Calculation Mode have no function.	Used exclusively in the following setups: AUS Region A 2020 AUS Region B 2020 AUS Region C 2020 NZS 2020
Power at Stop Voltage - Undervoltage	0 ‑ 100 [%]	Reference power when the set mains voltage limit value is reached. Only for devices with battery in charging mode.

Example: Setups AUS/NSZ 2020

Description of the parameter

Mode: On (without hysteresis)

(1)	Activation Threshold Undervoltage: 210 V
(2)	Stop at Voltage at Undervoltage: 200 V
(3)	Power at Stop Voltage - Undervoltage: 20 %

Charge power limitation when Activation Threshold Undervoltage is exceeded.

Frequency-dependent Power Control
, also called frequency/watt function or P(f) function, causes a change in effective power depending on the mains frequency.
A distinction is made between:

Overfrequency
Underfrequency

When the function is activated and the specified mains frequency limit value is exceeded, the effective power

is reduced according to a defined gradient in the event of an overfrequency (in the case of an inverter with an energy storage device, discharge of the storage device is stopped first before the power of the PV generator is reduced).
is increased in the event of underfrequency in accordance with a defined gradient (in the case of an inverter without an energy storage device or with active grid support deactivated, only possible in conjunction with a manual power reduction and corresponding priority).

The gradients result depending on the parameter Configuration Method:

Gradient: The gradient is given in %/Hz in relation to the device nominal output or the momentary power when entering the function (see example 1).
Stop Frequency: With this method, the gradient always results from the current power at entry into the function to the stop frequency set in the setup and power at stop frequency (see example 2).

In the case of an inverter with an energy storage device and active grid support activated, additional scenarios arise:

If the output power has already been reduced to 0 W at overfrequency and the frequency continues to rise, additional energy can be drawn from the grid (the battery is thus charged).
If the charging power (drawn from the grid) is reduced to 0 W at underfrequency and the frequency continues to drop, additional energy can be drawn from the battery to increase the output power.

SOC (State Of Charge) limits can be set for active grid support with battery. These can be found under Battery SoC Limitation for Grid Support:

Battery SoC Lower Limit - The battery will not be further discharged when the lower limit is reached.
Battery SoC Upper Limit - The battery will not be further charged when the upper limit is reached.

Once the mains frequency falls within the permitted frequency range again following successful power reduction, a return to the full power available takes place depending on the country setup as follows:

Mode: On (without Hysteresis)
The inverter increases the power from the current reduced value to the original value in accordance with the same gradient used for power reduction.
Mode: On (with Hysteresis)
The inverter will not increase the power to the original value until the frequency is back in the target value range for a specific length of time.

Example 1

Description of the parameter

P(f) Mode: On (without Hysteresis)
Configuration Method: Gradient
Active Grid Support: Off
Calculation Mode Underfrequency: P_max = P_m-P_n(k*df)
Calculation Mode Overfrequency: P_max = P_m-P_n(k*df)

(1)	Momentary effective power when the respective Activation Threshold is reached: 60 % of P_n (nominal output).
(2)	Gradient Underfrequency: 80 %/Hz - Increase of output power without battery only possible if sufficient power from the PV generator is available and manual power limitation is active. For this purpose, the Priority at Underfrequency parameter must be set to Priority on Frequency-dependent Power Limitation.
(3)	Activation Threshold Underfrequency: 49.7 Hz
(4)	Gradient Overfrequency: 60%/Hz
(5)	Activation Threshold Overfrequency: 50.3 Hz

General power curve with overfrequency and underfrequency without hysteresis with gradients.

Example 2

Description of the parameter

P(f) Mode: On (without Hysteresis)
Configuration Method: Stop frequency
Active Grid Support: Off

(1)	Momentary effective power when the respective Activation Threshold is reached: 60 % of P_n (nominal output).
(2)	Activation Threshold Underfrequency: 49.7 Hz
(3)	Stop Frequency - Underfrequency: 49.0 Hz
(4)	Power at Stop Frequency - Underfrequency: 85 %
(5)	Activation Threshold Overfrequency: 50.3 Hz
(6)	Stop Frequency - Overfrequency: 51.3 Hz
(7)	Power at Stop Frequency - Overfrequency: 20 %

General power curve with overfrequency and underfrequency without hysteresis with stop frequency.

Example 3

Description of the parameter

P(f) Mode: On (with Hysteresis)
Configuration Method: Gradient
Active Grid Support: Off
Calculation Mode Underfrequency: P_max = P_m-P_n(k*df)
Calculation Mode Overfrequency: P_max = P_m-P_n(k*df)

(1)	Momentary effective power when the respective Activation Threshold is reached: 60 % of P_n (nominal output).
(2)	Gradient Underfrequency: 80 %/Hz
(3)	Activation Threshold Underfrequency: 49.7 Hz
(4)	Lower Deactivation Threshold Underfrequency: 49.9 Hz
(5)	Upper Deactivation Threshold Underfrequency: 50.1 Hz
(6)	Gradient Overfrequency: 60 %/Hz
(7)	Activation Threshold Overfrequency: 50.3 Hz
(8)	Lower Deactivation Threshold Overfrequency: 49.9 Hz
(9)	Upper Deactivation Threshold Overfrequency: 50.1 Hz
(10)	Deactivation Time: 30 s

General power curve with overfrequency and underfrequency with hysteresis with gradients.

Parameter	Value range	Description	Availability
Mode	Off	The function is deactivated.
	On (with Hysteresis)	Function is activated with hysteresis.
	On (without Hysteresis)	Function is activated without hysteresis.	In the following setups On (without Hysteresis) is not possible: AUS Region A 2020 AUS Region B 2020 AUS Region C 2020 NZS 2020
Configuration Method	Gradient	For calculating the power limitation depending on the parameters Gradient Overfrequency or Gradient Underfrequency.
Configuration Method	Stop - Frequency	The gradient is calculated automatically using the parameters Stop Frequency - Overfrequency and Power at Stop Frequency - Overfrequency as well as Stop Frequency - Underfrequency and Power at Stop Frequency - Underfrequency.
Active Grid Support	Off	Deactivates extended active grid support for devices with a battery.	Has no influence on the following setups: AUS Region A 2020 AUS Region B 2020 AUS Region C 2020 NZS 2020
Active Grid Support	On	Activates extended active grid support for devices with a battery.

Overfrequency

Parameter	Value range	Description	Availability
Calculation Mode Overfrequency	P_max = P_m-P_m(k*df)	Indicates the reference power for calculating the power limit in the event of overfrequency. Reference power P_m → Momentary power when the frequency limit value is exceeded. P_n → Nominal output of the device.
	P_max = P_n-P_n(k*df)
	P_max = P_m-P_n(k*df)
Activation Threshold Overfrequency	45 ‑ 66 [Hz]	Frequency limit value above which the power reduction takes place.
Gradient Overfrequency	0.01 ‑ 300 [%/Hz]	Gradient by which the effective power is reduced. Example - conversion from static to gradient: Static s = 5 % → Gradient k = 1/(0.05*50Hz) = 40 %/Hz
Stop Frequency - Overfrequency	45 ‑ 66 [Hz]	Frequency value at which the power reduction ends.
Power at Stop Frequency - Overfrequency	-100 ‑ 0 [%]	Power when the set frequency limit value Stop Frequency - Overfrequency is reached. Adjustable between 0 % and full charging power (-100 %).
Upper Deactivation Threshold Overfrequency	45 ‑ 66 [Hz]	Used if Mode is set to On (with Hysteresis). If the mains frequency falls below this value, the frequency-dependent power reduction is terminated, taking into account the settings under Frequency-dependent Power Control - General.
Lower Deactivation Threshold Overfrequency	45 ‑ 66 [Hz]	Used if Mode is set to On (with Hysteresis). If this value is less than the Upper Deactivation Threshold Overfrequency, a frequency window results in which the mains frequency must be located to terminate the function. If this value is greater than or equal to the Upper Deactivation Threshold Overfrequency, it is not applied.
Transition Frequency at Overfrequency	45 ‑ 66 [Hz]	Frequency at which the device with active battery reaches an output power of 0 W. If the mains frequency continues to rise, energy is drawn from the national grid and thus the battery is charged. If there is no battery in the system or it is not active, this parameter has no function (behavior as in example 3 - overfrequency).	Used exclusively in the following setups: AUS Region A 2020 AUS Region B 2020 AUS Region C 2020 NZS 2020

Example 4: Setups AUS/NSZ 2020

Description of the parameter

P(f) Mode: On (with Hysteresis)
Active Grid Support: On
Battery is active

(1)	Momentary effective power when the respective Activation Threshold is reached: 60 % of P_n (nominal output).
(2)	The gradient for power reduction in generator-powered operation at overfrequency results automatically from the two set parameters Activation Threshold Overfrequency and Transition Frequency at Overfrequency
(3)	Activation Threshold Overfrequency: 50.25 Hz
(4)	Transition Frequency at Overfrequency: 50.75 Hz
(5)	The gradient for increasing the charging power at overfrequency results automatically from the two set parameters Transition Frequency at Overfrequency and Stop Frequency - Overfrequency. Depending on the set country setup, the power at stop frequency refers to drawing 100 % from the national grid. The parameter Power at Stop Frequency - Overfrequency has no function in these countries.
(6)	Stop Frequency - Overfrequency: 52.0 Hz
(7)	Upper Deactivation Threshold Overfrequency: 50.0 Hz - When the mains frequency returns to or below the set limit value, the effective power may be increased again.
(8)	Deactivation Time: 20 s - The frequency must be in the valid range for at least this time before the function is terminated.
(9)	Return Gradient 1: Return to power before entering P(f) in percent per second.

Power curve at overfrequency with hysteresis.

Underfrequency

Parameter	Value range	Description	Availability
Calculation Mode Underfrequency	P_max = P_m-P_m(k*df)	Indicates the reference power for calculating the power limit in the event of underfrequency. Reference power P_m → Momentary power when the frequency limit value is exceeded. P_n → Nominal output of the device.
	P_max = P_n-P_n(k*df)
	P_max = P_m-P_n(k*df)
Activation Threshold Underfrequency	45 ‑ 66 [Hz]	Frequency limit value above which the power increase takes place.
Gradient Underfrequency	0 ‑ 100 [%/Hz]	Gradient by which the effective power increases. Example - conversion from static to gradient: Static s = 5 % → Gradient k = 1/(0.05*50Hz) = 40 %/Hz
Stop Frequency - Underfrequency	45 ‑ 66 [Hz]	Frequency value at which the power increase ends.
Power at Stop Frequency - Underfrequency	0 ‑ 100 [%]	Power when the set frequency limit value Stop Frequency - Underfrequency is reached. Adjustable between 0 % and full feed-in power (100 %).
Upper Deactivation Threshold Underfrequency	45 ‑ 66 [Hz]	Used when Mode is set to On (with Hysteresis). If this value is greater than the Lower Deactivation Threshold Underfrequency, there is a frequency window in which the mains frequency must be to terminate the function. If this value is less than or equal to the Lower Deactivation Threshold Underfrequency, it is not applied.
Lower Deactivation Threshold Underfrequency	45 ‑ 66 [Hz]	In use when Mode - On (with Hysteresis) is set. If the mains frequency exceeds this value, the function is terminated, taking into account the settings under Frequency-dependent Power Control - General.
Transition Frequency at Underfrequency	45 ‑ 66 [Hz]	Frequency at which the device with active battery reaches an output power of 0 W (charging power is reduced). If the mains frequency continues to drop, additional energy is released into the grid. This energy can come from the PV generator or from the battery. If there is no battery in the system or it is not active, this parameter has no function (behavior as in example 3 - underfrequency).	Used exclusively in the following setups: AUS Region A 2020 AUS Region B 2020 AUS Region C 2020 NZS 2020

Example 5: Setups AUS/NSZ 2020

Description of the parameter

P(f) Mode: On (with Hysteresis)
Active Grid Support: On
Battery is active

(1)	Momentary draw (charging power of the battery) when the respective Activation Threshold (3) is reached: 80 % of P_n (nominal output)
(2)	The gradient for reducing the charging power at underfrequency results automatically from the two set parameters Activation Threshold Underfrequency (3) and Transition Frequency at Underfrequency (4)
(3)	Activation Threshold Underfrequency: 49.75 Hz
(4)	Transition Frequency at Underfrequency: 49.0 Hz
(5)	The gradient for increasing the output power at underfrequency results automatically from the two set parameters Transition Frequency at Underfrequency (4) and Stop Frequency - Underfrequency (6). Depending on the set country setup, the power at stop frequency refers to 100 % output power (nominal output of the inverter). The parameter Power at Stop Frequency - Underfrequency has no function in these countries.
(6)	Stop Frequency - Underfrequency: 48.0 Hz
(7)	Lower Deactivation Threshold Underfrequency: 50.0 Hz - When the mains frequency returns to or above the set limit value, the effective power may return to the value before entering the function.
(8)	Deactivation Time: 20 s - The frequency must be in the valid range for at least this time before the function is terminated.
(9)	Return Gradient 1: Return to power before entering P(f) in percent per second.

Power curve at underfrequency with hysteresis.

General - Frequency-dependent Power Control

Parameter

Value range

Description

Availability

Return Gradient 1

0.01 ‑ 100 [%/s]

Rate of change at which the inverter increases the effective power after the limitation has ended.

Return Gradient 1 Alternative

0.01 ‑ 100 [%/s]

Rate of change at which the inverter increases the effective power after the limitation has ended. This is activated if the difference between the rated power and the current reduced power is greater than the Return Gradient 1 Alternative Threshold.

Return Gradient 1 Alternative Threshold

0 ‑ 100 [W%]

Threshold value from which Return Gradient 1 or Return Gradient 1 Alternative is applied.

Example:
If the difference between the rated power and the currently reduced power is less than or equal to the threshold value, Return Gradient 1 is applied. If the difference between the rated power and the current reduced power is greater than or equal to the threshold, Return Gradient 1 Alternative is applied. 0.01 - 100 %. 100 % means that Return Gradient 1 is always applied.

Example 6

Description of the parameter

P_m	Actual power at the moment the limit value is exceeded
P_red	Reduced power
(1)	Gradient Overfrequency
(2)	Deactivation Time
(3)	Return Gradient 1
(4)	Return Gradient 1 Alternative
(5)	Return Gradient 1 Alternative Threshold: P_m - P_red <= 25 %
(6)	Return Gradient 1 Alternative Threshold: P_m - P_red > 25 %
(7)	Intentional Delay

The mains frequency returns to the permissible range at P_red.
After the waiting time (2) has elapsed, the power is increased to the initial value P_m with one of the following gradients:

Gradient 1 - red
The difference between the current power P_m and the reduced power P_red is ≤ Return Gradient 1 Alternative Threshold of 25 % (5). Thus, the power is increased to the initial value P_m with Return Gradient 1 (3).

Gradient 2 - grey
The difference between the current power P_m and the reduced power P_red is > Return Gradient 1 Alternative Threshold of 25 % (5). This increases the power to the output value P_m with Return Gradient 1 Alternative (4).

Application example with Return Gradient 1 Alternative and Return Gradient 1 Alternative Threshold.

Parameter	Value range	Description
Return Gradient 2 Mode	Off	Deactivates the use of Return Gradient 2. Raising the effective power from the reduced value to the device rated output takes place according to Return Gradient 1.
Return Gradient 2 Mode	On	Activates a different rate of change at which the inverter increases the effective power from the original value to the device nominal output. Raising the effective power from the original value to the device rated output takes place according to Return Gradient 2.
Return Gradient 2	0.01 ‑ 100 [%/s]	Rate of change at which the inverter increases the effective power from the original value to the device nominal output.

Example 7

Description of the parameter

Return Gradient 2 Mode = On

P_m	Actual power at the moment the limit value is exceeded
P_red	Reduced power
(1)	Gradient Overfrequency
(2)	Deactivation Time
(3)	Return Gradient 1
(4)	Return Gradient 2
(5)	Intentional Delay

At P_red the mains frequency returns to the permissible range. After the end of the waiting time (2), the power is increased to the initial value P_m with Return Gradient 1. The power is then increased to the device nominal output P_n with Return Gradient 2 (4).

Application example with Return Gradient 2 Mode.

Parameter	Value range	Description
Deactivation Time	0 ‑ 600 [s]	Used when Mode is set to On (with Hysteresis). Waiting time after which the inverter increases the power again (after the mains frequency is again within the permitted frequency range between Upper Deactivation Threshold and Lower Deactivation Threshold).
Intentional Delay	0.5 ‑ 60 [s]	Delays the start of the frequency-dependent power control after exceeding the respective Activation Threshold.
Time Constant (τ)	0 ‑ 60 [s]	Time constant (1 Tau) in seconds [s]. Whenever the set value is changed, this new set value is not triggered abruptly, but smoothly in accordance with a PT1 response. The time constant describes how quickly the new set value is reached. (After three time constants the final value 95 % is reached)

Battery SoC Limitation for Grid Support

Parameter	Value range	Description
Mode	Off	Deactivated SoC limitation
Mode	On	Activated SoC limitation
Battery SoC Lower Limit	0 ‑ 100 %	The battery is not further discharged when the lower limit is reached.
Battery SoC Upper Limit	0 ‑ 100 %	The battery is no longer charged when the upper limit is reached.

General - Active Power

Parameter	Value range	Description	Availability
Priority at Underfrequency	Priority on Manual Power Limitation	With Priority on Manual Power Limitation the power is not increased above the set limit in case of underfrequency.
Priority at Underfrequency	Priority on Frequency-dependent Power Limitation	With Priority on Frequency-dependent Power Limitation the manual power limitation is ignored in case of underfrequency and the output power is increased depending on the frequency. The prerequisite is that sufficient energy is available from the PV generator or the battery.

The voltage in the national grid can be influenced by the controlled use of reactive power by the inverter. When using reactive power control, the effective power generated at the same time is not affected or is only affected to a small extent.

IMPORTANT!
The exchange of reactive power (in addition to the feed-in of effective power) increases the current by the factor 1/cos φ.

Largely regardless of the effective power and therefore regardless of the energy yield, switching the reactive power can cause the voltage to both rise and to fall:

In over-excited mode or capacitive mode, reactive power is supplied to the national grid. This increases the mains voltage.
In under-excited mode or inductive mode, reactive power is taken from the inverter. The mains voltage is lowered as a result.

Potential operating range
Reactive power mode is restricted by the maximum apparent power S_n (and the maximum output current) as well as by the operational reactive power limits of the inverter:

Primo GEN24: Q_max = 60 % of S_n (or cos φ = 0.80 at S_n)
Symo GEN24: Q_max = 71 % of S_n (or cos φ = 0.70 at S_n)
Tauro: Q_max = 100 % of S_n (or cos φ = 0.00)
Verto: Q_max = 100 % of S_n (or cos φ = 0.00)

The value range specified for the following parameters may be additionally limited by the selected country-specific settings.
The following figure shows the possible operating range of the inverter. All valid operating points defined by effective power P and reactive power Q are within the grey area.

Example: Primo GEN24

General settings

Parameter	Range of values	Description
Mode		Reactive power mode selection option. The following modes are described in the subchapters.
	Off	No reactive power is fed in.
	Cos φ - Constant Power Factor	Constant Cos φ.
	Q Absolute - Constant Reactive Power	Constant reactive power in [Var].
	Q Relative - Constant Reactive Power	Constant reactive power in percent [%] of S_n.
	Cos φ(P) - Power dependent Power Factor Characteristic	Effective power-dependent Cos φ control.
	Q(P) - Power dependent Reactive Power Characteristic	Effective power-dependent reactive power control.
	Q(U) - Voltage dependent Reactive Power Characteristic	Mains voltage dependent reactive power control.
P/Q Priority	Q Priority	When the maximum apparent power is reached, the setting Q Priority leads to a reduction of the effective power in favor of reaching the reactive power specification.
P/Q Priority	P Priority	The setting P Priority leads to a reduction of the reactive power in favor of reaching the available effective power when the maximum apparent power is reached.
Cos φ Minimum	0 ‑ 1	Minimum cos φ, which together with the maximum apparent power forms an additional limitation of the reactive power at low effective power.

Depending on the selected mode, only the setting options in the respective subchapter and these general settings have an effect.

const cos φ
Reactive power default defined by a constant cos φ. The function is limited by the maximum apparent power and Cos φ minimum, the P/Q priority has no effect.

Parameter	Range of values	Description
cos φ - Power Factor	0 ‑ 1	Set value of Cos φ
Direction / Excitation		The current direction corresponds to the generator counter arrow system.
	Over-Excited	Over-excited operation = capacitive operation = reactive power is supplied = reactive current is fed-in lagging the active current.
	Under-Excited	Under-excited operation = inductive operation = reactive power is drawn = reactive current is fed-in ahead of the active current.
Time Constant (τ)	0.01 s ‑ 60 s	Time constant (1 Tau) in seconds [s]. Whenever the set value is changed, this new set value is not triggered abruptly, but smoothly in accordance with a PT1 response. The time constant describes how quickly the new set value is reached. (After three time constants the final value 95 % is reached)

Q Absolute - Constant Reactive Power
Reactive power specification defined by a constant value [Var]. The function is limited by the maximum apparent power and by Cos φ Minimum

Parameter	Range of values	Description
Q - Reactive Power (Var)	-200,000 Var - 200,000 Var	Reactive power setting value in [Var] (set value)
Time Constant (τ)	0.01 s ‑ 60 s	Time constant (1 Tau) in seconds [s]. Whenever the set value is changed, this new set value is not triggered abruptly, but smoothly in accordance with a PT1 response. The time constant describes how quickly the new set value is reached. (After three time constants the final value 95 % is reached)

Q Relative - Constant Reactive Power
Reactive power specification defined by a constant value in percent [%], related to the nominal apparent power (S_n) of the inverter. The function is limited by the maximum apparent power and by Cos φ Minimum.

Parameter	Range of values	Description
Q - Reactive Power (% of Nominal Apparent Power)	-100 % - 100 %	Reactive power setting as a percentage [%] of the nominal apparent power (set value)
Time Constant (τ)	0.01 s ‑ 60 s	Time constant (1 Tau) in seconds [s]. Whenever the set value is changed, this new set value is not triggered abruptly, but smoothly in accordance with a PT1 response. The time constant describes how quickly the new set value is reached. (After three time constants the final value 95 % is reached)

Cos φ(P) - Power dependent Power Factor Characteristic
This function controls the cos φ depending on the momentary effective power according to a characteristic curve. The characteristic curve is defined by four data points (1‑2‑3‑4). If fewer data points are required, the identical parameters can be set for two points. The function is limited by the maximum apparent power and by Cos φ Minimum. For the characteristic curves, the data points must be entered in the X‑axis (effective power) and in the Y‑axis (Cos φ).

Point	Parameter	Range of values	Description
1	Active Power (% of Nominal Apparent Power)	0 % ‑ 100 %	Effective power as a percentage of the nominal apparent power S_n.
	cos φ - Power Factor	0 ‑ 1	Set value of Cos φ.
	Direction / Excitation		The current direction corresponds to the generator counter arrow system.
		Under-Excited	Under-excited operation = inductive operation = reactive power is drawn = reactive current is fed-in ahead of the active current.
		Over-Excited	Over-excited operation = capacitive operation = reactive power is supplied = reactive current is fed-in lagging the active current.
2	Active Power (% of Nominal Apparent Power)	0 % ‑ 100 %	Effective power as a percentage of the nominal apparent power S_N.
	cos φ - Power Factor	0 ‑ 1	Set value of Cos φ.
	Direction / Excitation		The current direction corresponds to the generator counter arrow system.
		Under-Excited	Under-excited operation = inductive operation = reactive power is drawn = reactive current is fed-in ahead of the active current.
		Over-Excited	Over-excited operation = capacitive operation = reactive power is supplied = reactive current is fed-in lagging the active current.
3	Active Power (% of Nominal Apparent Power)	0 % ‑ 100 %	Effective power as a percentage of the nominal apparent power S_N.
	cos φ - Power Factor	0 ‑ 1	Set value of Cos φ.
	Direction / Excitation		The current direction corresponds to the generator counter arrow system.
		Under-Excited	Under-excited operation = inductive operation = reactive power is drawn = reactive current is fed-in ahead of the active current.
		Over-Excited	Over-excited operation = capacitive operation = reactive power is supplied = reactive current is fed-in lagging the active current.
4	Active Power (% of Nominal Apparent Power)	0 % ‑ 100 %	Effective power as a percentage of the nominal apparent power S_N.
	cos φ - Power Factor	0 ‑ 1	Set value of Cos φ.
	Direction / Excitation		The current direction corresponds to the generator counter arrow system.
		Under-Excited	Under-excited operation = inductive operation = reactive power is drawn = reactive current is fed-in ahead of the active current.
		Over-Excited	Over-excited operation = capacitive operation = reactive power is supplied = reactive current is fed-in lagging the active current.

Example: Curve defined by four data points.

1	P = 15 %, cos φ = 0.85 - Over-Excited
2	P = 25 %, cos φ = 1 - Over-Excited
3	P = 45 %, cos φ = 1 - Over-Excited
4	P = 90 %, cos φ = 0.9 - Under-Excited

General
In addition to the four points, the following parameters also come into play:

Parameter	Range of values	Description	Supplementary description
Lock-In Voltage-Dependent (% of Nominal Voltage)	0 % ‑ 120 %	AC voltage as a percentage of the nominal voltage. If this value is exceeded, the Cos φ(P) characteristic is activated.	With the voltage-dependent Lock-In/Lock-Out values it can be set that the Cos φ(P) control is deactivated at low voltages. The different values for activation (Lock-In) and deactivation (Lock-Out) enable a hysteresis to avoid unintentionally frequent switching on/off of the function. For this, the Lock-In value must be greater than the Lock-Out value.
Lock-Out Voltage-Dependent (% of Nominal Voltage)	0 % ‑ 120 %	AC voltage as a percentage of the nominal voltage. If this value is undershot, the Cos φ(P) characteristic is deactivated. The lock-out limit has priority over the lock-in limit.
Lock-Out P-Dependent (% of Nominal Apparent Power)	0 % ‑ 100 %	Effective power as a percentage of the nominal apparent power S_N. If this value is undershot, the Cos φ(P) characteristic is deactivated.	With the effective power-dependent lock-out values, it can be set that the cos φ(P) control is deactivated for small effective powers. For characteristic curves with a cos φ not equal to 1 at data point 1, a cos φ of 1 is approached again when the effective power value falls below this value. Otherwise, for effective powers that are lower than defined in data point 1, the cos φ belonging to data point 1 remains active.
Time Constant (τ)	0.01 s ‑ 60 s	Time constant (1 Tau) in seconds [s]. Whenever the set value is changed, this new set value is not triggered abruptly, but smoothly in accordance with a PT1 response. The time constant describes how quickly the new set value is reached. (After three time constants the final value 95 % is reached)

Q(P) - Power dependent Reactive Power Characteristic
This function controls the reactive power depending on the momentary effective power according to a characteristic curve. The characteristic curve is defined by four data points (1‑2‑3‑4). If fewer data points are required, the identical parameters can be set for two points. The function is limited by the maximum apparent power and by Cos φ Minimum. For the characteristic curves, the data points in the X‑axis (effective power) and in the Y‑axis (reactive power) must be entered.

Point	Parameter	Range of values	Description
1	Active Power (% of Nominal Apparent Power)	0 % ‑ 100 %	Effective power as a percentage of the nominal apparent power S_n (X‑axis).
1	Reactive Power (% of Nominal Apparent Power)	-100 % ‑ 100 %	Reactive power as a percentage of the nominal apparent power S_n (Y‑axis).
2	Active Power (% of Nominal Apparent Power)	0 % ‑ 100 %	Effective power as a percentage of the nominal apparent power S_n (X‑axis).
2	Reactive Power (% of Nominal Apparent Power)	-100 % ‑ 100 %	Reactive power as a percentage of the nominal apparent power S_n (Y‑axis).
3	Active Power (% of Nominal Apparent Power)	0 % ‑ 100 %	Effective power as a percentage of the nominal apparent power S_n.
3	Reactive Power (% of Nominal Apparent Power)	-100 % ‑ 100 %	Reactive power as a percentage of the nominal apparent power S_n (Y‑axis).
4	Active Power (% of Nominal Apparent Power)	0 % ‑ 100 %	Effective power as a percentage of the nominal apparent power S_n (X‑axis).
4	Reactive Power (% of Nominal Apparent Power)	-100 % ‑ 100 %	Reactive power as a percentage of the nominal apparent power S_n (Y‑axis).

Example: Curve defined by four data points.

1	P = 0 %, Q = 0 %
2	P = 25 %, Q = 0 %
3	P = 50 %, Q = 0 %
4	P = 95 %, Q = -32 %

In addition to the four points, the following parameters also come into play:

Parameter	Range of values	Description	Supplementary description
Lock-In Voltage-Dependent (% of Nominal Voltage)	0 % ‑ 120 %	AC voltage as a percentage of the nominal voltage. If this value is exceeded, the Q(P) characteristic is activated.	With the voltage-dependent Lock-In/Lock-Out values, it can be set that the Q(P) control is deactivated at low voltages. The different values for activation (Lock-In) and deactivation (Lock-Out) enable a hysteresis to avoid unintentionally frequent switching on/off of the function. For this, the Lock-In value must be greater than the Lock-Out value.
Lock-Out Voltage-Dependent (% of Nominal Voltage)	0 % ‑ 120 %	AC voltage as a percentage of the nominal voltage. If this value is undershot, the Q(P) characteristic is deactivated. The lock-out limit has priority over the lock-in limit.
Lock-Out P-Dependent (% of Nominal Apparent Power)	0 % ‑ 100 %	Effective power as a percentage of the nominal apparent power S_N. If this value is undershot, the Q(P) characteristic is deactivated.	With the effective power-dependent lock-out values, it can be set that the Q(P) control is deactivated at low active powers. For characteristic curves with a reactive power not equal to 0 % at data point 1, a reactive power of 0 % is approached again when this effective power value is undershot. Otherwise, in the case of effective powers which are lower than defined in data point 1, the reactive power belonging to data point 1 remains active.
Time Constant (τ)	0.01 s ‑ 60 s	Time constant (1 Tau) in seconds [s]. Whenever the set value is changed, this new set value is not triggered abruptly, but smoothly in accordance with a PT1 response. The time constant describes how quickly the new set value is reached. (After three time constants the final value 95 % is reached)

Q(U) - Voltage-dependent Reactive Power Characteristic
This function controls the reactive power as a function of the momentary mains voltage according to a characteristic curve. The characteristic curve is defined by four data points (1‑2‑3‑4). If fewer data points are required, the identical parameters can be set for two points. The function is limited by the maximum apparent power and by Cos φ Minimum. For the characteristic curves, the data points in the X‑axis (voltage) and in the Y‑axis (reactive power) must be entered.

Point	Parameter	Range of values	Description
1	Voltage (% of Nominal Voltage)	50 % ‑ 150 %	AC voltage as a percentage of the nominal voltage (X‑axis).
1	Reactive Power (% of Nominal Apparent Power)	-100 % ‑ 100 %	Reactive power as a percentage of the nominal apparent power S_n (Y‑axis).
2	Voltage (% of Nominal Voltage)	50 % ‑ 150 %	AC voltage as a percentage of the nominal voltage (X‑axis).
2	Reactive Power (% of Nominal Apparent Power)	-100 % ‑ 100 %	Reactive power as a percentage of the nominal apparent power S_n (Y‑axis).
3	Voltage (% of Nominal Voltage)	50 % ‑ 150 %	AC voltage as a percentage of the nominal voltage (X‑axis).
3	Reactive Power (% of Nominal Apparent Power)	-100 % ‑ 100 %	Reactive power as a percentage of the nominal apparent power S_n (Y‑axis).
4	Voltage (% of Nominal Voltage)	50 % ‑ 150 %	AC voltage as a percentage of the nominal voltage (X‑axis).
4	Reactive Power (% of Nominal Apparent Power)	-100 % ‑ 100 %	Reactive power as a percentage of the nominal apparent power S_n (Y‑axis).

General
In addition to the four points, the following parameters also come into play:

Parameter	Range of values	Description	Supplementary description
Offset Factor	-1 ‑ 1	Shift of the Q(U) characteristic on the Y‑axis (Q‑axis) via an offset factor. The offset factor is related to the reactive power set in point 1 or point 4, by which the characteristic curve continues to be limited.
Initial Delay Time	0 s ‑ 60 s	Start-up delay in seconds [s] - Delays the start of the Q(U) control when leaving the voltage range between the data point 2 and the data point 3.
Lock-In P-Dependent (% of Nominal Apparent Power)	0 % ‑ 120 %	Effective power as a percentage of the nominal apparent power S_n. If this value is exceeded, the Q(P) characteristic is activated.	With the power-dependent Lock-In/Lock-Out values, it can be set that the Q(U) control is deactivated at low powers. The different values for activation (Lock-In) and deactivation (Lock-Out) enable a hysteresis to avoid unintentionally frequent switching on/off of the function. For this, the Lock-In value must be greater than the Lock-Out value.
Lock-Out P-Dependent (% of Nominal Apparent Power)	0 % ‑ 100%	Effective power as a percentage of the nominal apparent power S_N. If this value is undershot, the Q(P) characteristic is deactivated. The lock-out limit has priority over the lock-in limit.
Time Constant (τ)	0.01 s ‑ 60 s	Time constant (1 Tau) in seconds [s]. Whenever the set value is changed, this new set value is not triggered abruptly, but smoothly in accordance with a PT1 response. The time constant describes how quickly the new set value is reached. (After three time constants the final value 95 % is reached)

Shift of the Q(U) characteristic on the Y-axis (Q-axis) via an offset factor.

Example: Curve defined by four data points.

1	U = 95 %, Q = 32 %
2	U = 97 %, Q = 0 %
3	U = 104 %, Q = 0 %
4	U = 105 %, Q = -32 %
(1)	Lock-Out P-Dependent (% of Nominal Apparent Power) = 5 %
(2)	Lock-In P-Dependent (% of Nominal Apparent Power) = 30 %
(3)	Cos φ minimum = 0.9

GEN24, Tauro and Verto Country Setup Menu

General

How information is presented in the document

How information is presented in the document

Country setup

WARNING!

NOTE!

NOTE!

Territorial Limitations

Requesting inverter codes in Solar.SOS

CAUTION!

Adjusting parameters with the Fronius Solar.start app

Adjusting parameters with the browser

Country setup

Country setup selection

Country setup selection

Country setup selection

Country setup selection

Country setup selection

General

Startup and Reconnection

Startup and Reconnection

Ramp rates

Safety

Unintentional islanding detection

Unintentional islanding detection

Isolation monitoring

DC arc fault protection

RCMU

DC shutdown communication

Interface protection

Voltage

Voltage

Frequency

Export Limit Protection

DC injection

Grid support functions

Voltage fault ride through (VFRT)

Voltage fault ride through (VFRT)

Active Power

Reactive power