Fronius GEN24 and Tauro Country Setup Menu Operating Instruction [EN]

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Operating Instructions

GEN24 & Tauro Country Setup Menu

Operating Instructions

42,0426,0413,EN 009-09012023

Contents

General 4

Country setup 4 Access code 4 Adjusting parameters with the Fronius Solar.start app 5 Adjusting parameters with the browser 5

Country setup 7

Country setup selection 9

General 10

Startup and Reconnection 10 Ramp Rates 11

Safety 14

Unintentional Islanding Detection 14 Isolation monitoring 14 DC Arc Fault Protection 16 RCMU 18 DC Shutdown Communication 19

Interface Protection 20

Voltage 20 Frequency 23 DC Injection 27

Grid Support Functions 29

Voltage Fault Ride Through (VFRT) 29 Active Power 41 Reactive Power 63

General

Country setup The "Country Setup" menu area is intended exclusively for installers/service

technicians from authorised specialist companies. The access code must be requested from the national/international Fronius point of contact using an application form.

CAUTION!

Risk due to unauthorised access.

Incorrectly set parameters can negatively inﬂuence the public grid and/or the inverter feeding energy into the grid, and lead to a loss of conformity with the standard.

The parameters may only be adjusted by installers/service technicians from

▶

authorised specialist companies. Do not give the access code to third parties and/or unauthorised persons.

▶

WARNING!

Danger due to unauthorised error analyses and repair work.

This can result in serious injury and damage to property.

Fault analyses and repair work on the photovoltaic system may only be car-

▶

ried out by installers/service technicians from authorized specialist companies in accordance with national standards and guidelines.

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 energy provider, adjustments to the selected country setup may be necessary.

CAUTION!

Risk due to incorrectly set parameters.

Incorrectly set parameters can negatively inﬂuence the public grid and/or cause faults and failures on the inverter, and lead to the loss of standard conformity.

The parameters may only be adjusted by installers/service technicians from

▶

authorised specialist companies. The parameters may only be adjusted if the energy provider permits or re-

▶

quires this. Only adjust the parameters taking into account the nationally applicable

▶

standards and/or directives and the specifications of the energy provider.

Access code The "Country setup" menu area is intended exclusively for installers/service tech-

nicians from authorised specialist companies. The access code must be requested from the national/international Fronius point of contact using an application form.

CAUTION!

1 2

open access point

Setup your PV system in a few minutes.

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Log in with your Fronius credentials (email adress & password) in order to get the most out of the PV System. Installing a new product does not require a Login.

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Fronius Solar.start

open access point

FRONIUS_PILOTxxx

Secured

Password:

12345678

192.168.250.181

Adjusting parameters with the Fronius Solar.start app

Risk due to unauthorised access.

Incorrectly set parameters can negatively inﬂuence the public grid and/or the inverter feeding energy into the grid, and lead to a loss of conformity with the standard.

The parameters may only be adjusted by installers/service technicians from

▶

authorised specialist companies. Do not give the access code to third parties and/or unauthorised persons.

▶

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

Adjusting parameters with the browser

Start the installation in the app.

Select the product to which the connection should be established.

Open the access point by touching the sensor once → Communication LED: ﬂashes blue.

Select the "Technician" user in the "User menu" and enter and confirm the

password for the "Technician" user.

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

Enter the requested access code (see chapter Access code on page 4) in the

input field "Access code country setup" and click the button "Activate".

Adjust the parameters in the individual menu areas taking into account the

nationally applicable standards and/or the specifications of the energy provider.

WLAN:

Open the access point by touching the sensor once → Communication LED: ﬂashes blue.

Establish the connection to the inverter in the network settings (the inverter

169.254.0.180

open access point

is displayed with the name "FRONIUS_PILOT" and the serial number of the device).

Password: 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.

In the browser address bar, enter and confirm the IP address

192.168.250.181.

Select the "Technician" user in the "User menu" and enter and confirm the

password for the "Technician" user.

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

Enter the requested access code (see chapter Access code on page 4) in the

input field "Access code country setup" and click the button "Activate".

Adjust the parameters in the individual menu areas taking into account the

nationally applicable standards and/or the specifications of the grid operator.

Ethernet:

Establish a connection to the inverter (LAN1) with a network cable (CAT5

STP or higher).

Open the access point by touching the sensor once → Communication LED: ﬂashes blue.

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

Select the "Technician" user in the "User menu" and enter and confirm the

password for the "Technician" user.

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

Enter the requested access code (see chapter Access code on page 4) in the

input field "Access code country setup" and click the button "Activate".

Adjust the parameters in the individual menu areas taking into account the

nationally applicable standards and/or the specifications of the grid operator.

Country setup

Country setup selection

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 energy provider, 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 coun-

try 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.

General

Startup and Reconnection

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 grid 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 grid 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"

Parameter Range of values Description

"Grid Monitoring Time Reconnection"

1 - 900 [s] Grid monitoring time before the invert-

er is switched on during a normal startup process in seconds (e.g. at sunrise).

1 - 900 [s] Grid monitoring time before the invert-

er 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

"Overvoltage" Mains voltage exceeds an

overvoltage limit ("Inner,

Middle, or Outer Limit Overvoltage").

"Undervoltage" Mains voltage falls below

an undervoltage limit ("In-

ner, Middle or Outer Limit Undervoltage").

"Overfrequency" Grid frequency exceeds an

overfrequency limit ("In-

ner, Outer or Alternative Limit Overfrequency").

"Underfrequency"

Grid frequency falls below an underfrequency limit ("Inner, Outer or Alternat-

ive Limit Underfrequency").

"AC voltage too high"

"AC voltage too low"

"AC frequency too high"

"AC frequency too low"

"StateCode"

number

1114

1119

1035

1037

"Fast Overvoltage Disconnect"

Triggering of the fast surge protection (> 135%).

"Grid voltage too high (fast overvoltage cut-out)"

1115, 1116

Name Description "StateCode"

name

"Long Time Average Overvoltage Limit"

Mains voltage exceeds the long-term overvoltage limit ("Long Time Average

Limit").

"Long-term mains voltage limit exceeded"

"StateCode"

number

1117

"Unintentional Islanding Detection."

Ramp Rates Ramp rates limit the maximum rate of change of effective power in special situ-

ations. 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 there are multiple rate of change specifications. An "Irradiation Ramp" can thus be rendered ineffective by, for ex- ample, 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

Unintentional islanding was detected.

"Islanding detected"

1004

"Ramp-Up at Startup and Reconnection"

"Ramp-Up at Startup and Reconnection Rate."

"Ramp-Up/Down Irradiation"

The "Irradiation Ramp" is a permanent limitation of the rate of change for the ef- fective 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"

"Ramp-Up Irradiation Rate"

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".

Off The function is deactivated.

0.001 ‑ 100 [%/s]

On The effective power increase is limited

Off The function is deactivated.

0.001 - 200 [%/s]

Permitted rate of change of the effective power at "Startup" or "Reconnec-

tion".

with a rate of change of "Ramp-Up Ir-

radiation Rate".

Permitted rate of change during power increase.

Parameter Range of values Description

"Ramp-Down Irradiation"

Note: This func-

tion only has an effect on inverters with storage.

"Ramp-Down Irradiation Rate"

Example: Effective power limitation by "Irradiation-Ramp-Up/Down", which was

caused by a change in the available PV power.

On The effective power reduction is limited

with a rate of change of "Ramp-Down

Irradiation Rate".

Off The function is deactivated.

0.001 - 200 [%/s]

Permitted rate of change of effective 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"

"Ramp-Up Communication Rate"

"Ramp-Down Communication"

On The limitation of the rate of change

(corresponding to "Ramp-Up Commu-

nication Rate") in case of effective

power increase due to an external specification is activated.

Off The function is deactivated.

0.001 ‑ 100 [%/s]

On The limitation of the rate of change

Off The function is deactivated.

Permitted rate of change during power increase.

(corresponding to "Ramp-Down Com-

munication Rate") in the event of ef-

fective power reduction due to an external specification is activated.

Parameter Range of values Description

"Ramp-Down Communication Rate"

0.001 ‑ 100 [%/s]

Permitted rate of change for power reduction.

Safety

Unintentional Islanding Detection

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. 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 feeding energy into the grid, 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 feeding energy into the grid and disconnects from the AC grid at all poles. The detection process is carried out using a grid frequency shift method (Active Frequency Drift): In the event of short-term grid 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 feeding energy into the grid. 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 behaviour during the detection process.

Standard

Parameter Range of values

"Unintentional Islanding Detection."

"Quality Factor" 0.1 ‑ 10.0 1.0 The higher this value, the

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".

On Active islanding detection

Off Off Active islanding detection

value Description

is activated.

is deactivated.

stronger/more aggressive the frequency shift of the island detection. Higher values therefore result in shorter island detection times. However, values that are too high can also have a negative effect on the voltage quality.

Isolation monitoring

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 Er-

ror Threshold", feeding energy into the grid 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.

The 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, feeding energy into the grid is prevented (if isolation monitoring is activated) and status code 1182 is displayed on the user interface of the inverter.

The 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.

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.

Quick Isolation monitoring is performed with

lower accuracy, which shortens the duration of the isolation measurement and the isolation value is not displayed.

Parameter Range of values Description

DC Arc Fault Protection

"Isolation Warning Threshold"

These parameters can be used to set the behaviour 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

"Arc Fault Detection (AFD)"

0.1 ‑ 10 MOhm If this value is undershot, status code 1183 is displayed on the user interface of the inverter.

Range of values Description

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.

"Arc-Fault Circuit Interrupter (CI)"

On The arc detection is active.

Describes the behaviour 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)

On If an arc is detected, the inverter inter-

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.

rupts feeding energy into the grid 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 feeding energy into the grid after 5 minutes. Furthermore, an integrated self-test is active, which is executed at regular intervals. If this fails, the inverter stops feeding energy into the grid and status code 1009 is displayed.

Parameter

"Automatic Reconnects"

Range of values Description

If more arcs have been detected within 24

hours than are defined in "Automatic Re-

connects", the inverter will not make any

further attempt to start feeding energy into the grid. 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 in-

verter restarts feeding energy into the grid 5 minutes after each arc detected.

0 - No Reconnection

1 ‑ 4 After a shutdown by an arc, 1, 2, 3 or 4 at-

"Arc Logging" Enables or disables the recording of arc

Off Arc signatures are not recorded.

On Arc signatures are recorded, uploaded to

After an arc has been detected, no further attempt is made to start feeding energy into the grid and status code 1173 is displayed on the user interface of the inverter.

tempts are made within 24 hours to restart feeding energy into the grid. After this number of attempts, no further attempt is made to start feeding energy into the grid and status code 1173 is displayed on the user interface of the inverter.

signatures. The data is uploaded to the cloud and used to continuously improve the interference immunity and fault tolerance of arc detection.

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 Prob-

ability" parameter, data is recorded and

uploaded to the cloud every 10 minutes.

Parameter

Range of values Description

"Recording Probability"

RCMU The inverter is equipped with a universal current-sensitive residual current monit-

oring 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 unauthorised residual current.

Parameter

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.

Range of values Description

"RCMU" Off The protective function is deactivated.

Off (with Warning)

On The protective function is activated.

The protective function is deactivated. The status code 1188 is permanently displayed on the user interface of the inverter.

Parameter

"Automatic Reconnects"

Range of values Description

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 feeding energy into the grid. 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 toler-

ated. After each detected fault current, feeding energy into the grid 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 ex-

ceeding 300 mA, 1, 2, 3 or 4 attempts are made within 24 hours to restart feeding energy into the grid. After this number of attempts, no further attempt is made to start feeding energy into the grid and the status code must be acknowledged manually on the user interface of the inverter.

DC Shutdown Communication

Unlimited The 24 hour counter is deactivated. The in-

verter restarts feeding energy into the grid 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.

Range of val-

Parameter

"Powerline Communication"

ues Description

Activates and deactivates DC Powerline

Communication (PLC) on the inverter.

PLC Off DC Powerline Communication is deactiv-

ated 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.

Interface Protection

Voltage 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 Lim-

its" (U<< for undervoltage; U>> for overvoltage).

For expedient use of the "Inner Limits" and "Outer Limits", the respective "In-

ner Limit" must be linked to a greater time than the "Outer Limit". If the "Middle Limits" are also used, their time between "Inner Limit" and "Outer Limit" must

be set, see example in the diagram.

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

Graphic illustrating the limits

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"

Protection time

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<<"

"Overvoltage U>>" Setting value for surge protection U>> in [V]

Setting value of time for undervoltage protection U<< in [s]

"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"

"Overvoltage Averaging Time U>"

"Overvoltage U>" Setting value of the surge protection with average

"Fast Overvoltage Disconnect"

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

Parameter Description

Activate / deactivate the voltage average limit value

"On" / "Off"

Time period over which the average value is calculated in [s]. (If 0 s is set, the check is not active)

value formation U> in [V]

"Fast Overvoltage Disconnect"

"Fast Overvoltage Disconnect Time"

"Startup and Reconnection"

Before the inverter is allowed to connect, the connection conditions for voltage

Activate / deactivate fast RMS overvoltage disconnect (exceeding 135 % of rated voltage) "On" / "Off"

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.

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 mains 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 Recon-

nection". The monitoring time used depends on whether it is "Startup" or "Reconnection" 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 / Recon-

nection Values are used for Reconnection": In

a normal startup process, the startup values are used as connection conditions. When reconnecting after a mains fault, the reconnection values are used as connection conditions.

"Startup Values are used for Startup and Re-

connection": Regardless of the type of con-

nection, the startup values are always used as connection conditions.

"Reconnection Minimum Voltage"

"Reconnection Maximum Voltage"

"Startup Minimum Voltage"

"Startup Maximum Voltage"

The following errors are defined by the inverter as grid errors for this functionality:

Name Description "StateCode"

"Overvoltage" Mains voltage exceeds an

overvoltage limit ("Inner,

Middle, or Outer Limit Overvoltage").

"Undervoltage" Mains voltage falls below

an undervoltage limit ("In-

ner, Middle or Outer Limit Undervoltage").

Lower value of the voltage for reconnection in [V]

Upper value of the voltage for reconnection in [V]

Lower value of the voltage for the normal start process in [V]

Upper value of the voltage for the normal start process in [V]

"StateCode"

name

"AC voltage too high"

"AC voltage too low"

number

1114

1119

Name Description "StateCode"

name

"Overfrequency" Grid frequency exceeds an

overfrequency limit ("In-

ner, Outer or Alternative Limit Overfrequency").

"AC frequency too high"

"StateCode"

number

1035

"Underfrequency"

"Fast Overvoltage Disconnect"

"Long Time Average Overvoltage Limit"

"Unintentional Islanding Detection."

Frequency This chapter deals with the protection settings for overfrequencies and underfre-

quencies. Grid frequency limit values are defined for this purpose. These depend on the country setup and can be adjusted as described below.

Grid frequency falls below an underfrequency limit ("Inner, Outer or Alternat-

ive Limit Underfrequency").

Triggering of the fast surge protection (> 135%).

Mains voltage exceeds the long-term overvoltage limit ("Long Time Average

Limit").

Unintentional islanding was detected.

"AC frequency too low"

"Grid voltage too high (fast overvoltage cut-out)"

"Long-term mains voltage limit exceeded"

"Islanding detected"

1037

1115, 1116

1117

1004

Each frequency limit value is defined by:

an underfrequency with associated protection time, or

an overfrequency with associated protection time.

The protection time describes the duration for which the frequency may be outside the respective frequency limit value before the inverter switches off with an error message. Two overfrequency and two underfrequency limit values can be used. The "Inner Limits" (f< for underfrequency; f>for overfrequency) are those limit values which are closer to the rated frequency than the "Outer Limits" (f<< for underfrequency; f>> for overfrequency). For the sensible use of both ranges, the respective "Inner Limit" must be linked to a larger time than the "Outer Lim-

it".

IL "Inner limit" - inner limit value OL "Outer limit" - outer limit value (1) Trip range OF Overfrequency UF Underfrequency

Graphic illustrating the limits

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

"Inner Limits"

Parameter Description

"Underfrequency f<" Setting value of underfrequency protection f< in

[Hz]

"Underfrequency Time f<"

Setting value of time for underfrequency protection f< in [s]

"Overfrequency f>" Setting value of overfrequency protection f> in [Hz]

"Overfrequency Time f>"

Setting value of time for overfrequency protection f> in [s]

"Outer Limits"

Parameter Description

"Frequency Outer Limits"

Activate / deactivate the outer frequency limits

"On" / "Off"

"Underfrequency f<<" Setting value of underfrequency protection f<< in

[Hz]

"Underfrequency Time f<<"

Setting value of time for underfrequency protection f<< in [s]

"Overfrequency f>>" Setting value of overfrequency protection f<< in

[Hz]

"Overfrequency Time f>>"

Setting value of time for the overfrequency protection f>> in [s]

"Alternative Limits"

For the inner frequency limit values there is an additional second parameter set, which is only relevant for Italy. In order to activate this 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:

Activate: http://<IP>/status/SetSignaleEsterno

Deactivate: http://<IP>/status/ClearSignaleEsterno

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

Parameter Description

"Frequency Alternative Limits"

"Underfrequency f<" Setting value of alternative underfrequency protec-

"Underfrequency Time f<"

"Overfrequency f>" Setting value of alternative overfrequency protec-

"Overfrequency Time f>"

"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).

Activate / deactivate alternative frequency limit values "On" / "Off"

tion f< in [Hz]

Setting value of time for the alternative underfrequency protection f< in [s]

tion f> in [Hz]

Setting value of time for the alternative overfrequency protection f> in [s]

nection". The monitoring time used depends on whether it is "Startup" or "Reconnection" 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 / Recon-

nection Values are used for Reconnection": In

a normal startup process, the startup values are used as connection conditions. When reconnecting after a mains fault, the reconnection values are used as connection conditions.

"Startup Values are used for Startup and Re-

connection": Regardless of the type of con-

nection, the startup values are always used as connection conditions.

"Startup Values are used for Reconnection":

When reconnecting after a mains fault, the startup values are used as reconnection conditions. In a normal start-up procedure, the

"Frequency Inner Limits" f< and f>used as

connection conditions.

Parameter Description

"Reconnection Minimum Frequency"

"Reconnection Maximum Frequency"

"Startup Minimum Frequency"

"Startup Maximum Frequency"

The following errors are defined by the inverter as grid errors for this functionality:

Name Description "StateCode"

"Overvoltage" Mains voltage exceeds an

overvoltage limit ("Inner,

Middle, or Outer Limit Overvoltage").

"Undervoltage" Mains voltage falls below

an undervoltage limit ("In-

ner, Middle or Outer Limit Undervoltage").

Lower value of the grid frequency for reconnection in [Hz]

Upper value of the grid frequency for reconnection in [Hz]

Lower value of the grid frequency for the normal start process in [Hz]

Upper value of the grid frequency for the normal start process in [Hz]

"StateCode"

name

"AC voltage too high"

"AC voltage too low"

number

1114

1119

"Overfrequency" Grid frequency exceeds an

overfrequency limit ("In-

ner, Outer or Alternative Limit Overfrequency").

"Underfrequency"

"Fast Overvoltage Disconnect"

"Long Time Average Overvoltage Limit"

"Unintentional Islanding Detection."

"Rate of Change of Frequency (RoCoF) Protection"

This function allows the RoCoF (Rate of Change of Frequency) ‑detection and ‑switch-off to be activated and adjusted. In the event of frequency changes that

are above a set value and last longer than the set time, the inverter is shut down.

Grid frequency falls below an underfrequency limit ("Inner, Outer or Alternat-

ive Limit Underfrequency").

Triggering of the fast surge protection (> 135%).

Mains voltage exceeds the long-term overvoltage limit ("Long Time Average

Limit").

Unintentional islanding was detected.

"AC frequency too high"

"AC frequency too low"

"Grid voltage too high (fast overvoltage cut-out)"

"Long-term mains voltage limit exceeded"

"Islanding detected"

1035

1037

1115, 1116

1117

1004

RoCoF detection can be used as a passive stand-alone operation detection method.

Parameter Description

"Rate of Change of Frequency (RoCoF) Protection."

"ROCOF Limit" Setting value of the frequency change protection in

"RoCoF Time" Setting value of time for the RoCoF protection in [s]

DC Injection DC injection means the injection of an AC current into the public grid that is un-

intentionally 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. Internal and external 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"

Activate and deactivate the RoCoF protection.

"On" / "Off

[Hz/s]

Range of val-

Parameter

"Mode" Off Monitoring of the inner limit is deactiv-

"DC Current Absolute Value"

"DC Current Relative Value"

ues Description

ated.

Absolute DC component monitoring with an abso-

lute current limit in [A].

Relative DC component monitoring with a relative

current limit in [%] referred to the nominal current of the inverter.

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", feeding energy into the grid is interrupted with status code 1052. This limit only applies to the "Absolute" mode.

0.0 % ‑ 10.0 % Relative DC current limit in [%] referred to 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", feeding energy into the grid is interrupted with status code 1052. This limit only applies to the "Relative" mode.

Parameter

Range of values Description

"DC Injection Time"

"Outer Limit"

Parameter

"Mode" Off Monitoring of the outer limit is deactiv-

"DC Current Absolute Value"

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.

Range of values Description

ated.

Absolute DC component monitoring with an abso-

lute current limit in [A].

Relative DC component monitoring with a relative

current limit in [%] referred to the nominal current of the inverter.

"DC Current Relative Value"

"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.

Grid Support Functions

Voltage Fault Ride Through (VFRT)

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. Grid 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 grid 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 behaviour of the inverters during the fault depend on the respective grid connection rules. The following parameters determine this behaviour.

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 behaviour of the inverter within that region. The detection limit is a relative voltage level and is specified in percent derived from 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.

Standard

Parameter Value range

"Mode" On VFRT function is active ac-

Off Off If no special behaviour is

value Description

cording to the set parameter values.

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."

"Reactive Current Limit for Underexcited Operation."

0 ‑ 110 [% IacNominal]

100 % Limitation of the reactive

current during a mains voltage fault and overexcited operation - in percent [%] related to the nominal current lN.

This parameter is only effective for the current inrush mode "Active Asym-

metric Current".

100 % Limitation of the reactive

current during a mains voltage fault and underexcited operation - in percent [%] related to the nominal current lN.

This parameter is only effective for the current inrush mode "Active Asym-

metric Current".

Parameter Value range

"Sudden Voltage Change Detection"

On The detection of sudden

Off Off No detection of sudden

Standard value Description

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.

voltage changes within the normal voltage range.

"Insensitivity Range"

"Deactivation Time"

0 ‑ 100 [% Uac 1s‑Avg]

0 ‑ 100 [s] 5 s Time duration of mains

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).

fault handling for sudden voltage changes. After this time has elapsed, the mains 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.

Standard

Parameter Value range

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").

Parameter Value range

"Static Detection Mode"

Voltage system used for

L-N Voltage L-N Voltage The phase-to-neutral (line-

L-L Voltage The phase-to-phase (line-

Standard value Description

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.

to-neutral) voltage system is used for static threshold detection of VFRT Region

to-line) voltage system is used for static threshold detection of VFRT Region

L-L and L-N Voltage

Both voltage systems

(line-to-neutral and lineto-line) are used for static threshold detection of VFRT Region 1.

Parameter Value range

Standard value Description

"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 active cur-

rent and reactive current is maintained for as long as the fault persists.

Zero Current Zero Cur-

rent

Active Symmetric Current

A symmetrical reactive

The alternating current is adjusted to zero. There is no effective or reactive power feed-in during the fault.

current (positive-sequence system reactive current) is fed into the grid. The amount of the additional reactive current results from the "k-factor Posit-

ive Sequence" multiplied

by the amount of the voltage dip. No active current is fed in.

"k-factor Positive Sequence"

Active Asymmetric Current

0 ‑ 10 2.0 Multiplication factor (k-

An additional reactive cur-

rent is fed into the grid. At the same time, active current is fed in (whereby the reactive current has priority). The amount of additional reactive current results from the k-factors multiplied by the amount of the voltage dip. If the

"k-factor Negative Sequence" is set to 0, the

feed is symmetrical. Otherwise, asymmetrical faults are responded to with an asymmetrical current in-feed.

factor) for the positive-sequence system reactive current in Region 1. Only applied with current inrush mode "Active Sym-

metric Current" and "Active Asymmetric Current".

Standard

Parameter Value range

"k-factor Negative Sequence"

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

0 ‑ 10 2.0 Multiplication factor (k-

value Description

factor) for the negativesequence 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 symmetrical supply is required, this is set to 0.

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").

Parameter Value range

Standard value Description

"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

L-L Voltage The phase-to-phase (line-

to-line) voltage system is used for static threshold detection of VFRT Region

L-L and L-N Voltage

Both voltage systems

(line-to-neutral and lineto-line) are used for static threshold detection of VFRT Region 2.

Parameter Value range

"Current Calc Mode"

Current inrush mode for

Standard value Description

Region 2. This parameter defines the type of current feed during a Region 2 voltage fault.

Passive The pre-fault active cur-

rent and reactive current is maintained for as long as the fault persists.

Zero Current Zero Cur-

rent

Active Symmetric Current

Active Asymmetric Current

A symmetrical reactive

An additional reactive cur-

The alternating current is adjusted to zero. There is no effective or reactive power feed-in during the fault.

current (positive-sequence system reactive current) is fed into the grid. The amount of the additional reactive current results from the "k-factor Posit-

ive Sequence" multiplied

by the amount of the voltage dip. No active current is fed in.

"k-factor Negative Sequence" is set to 0, the

feed is symmetrical. Otherwise, asymmetrical faults are responded to with an asymmetrical current in-feed.

"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 Sym-

metric Current" and "Active Asymmetric Current".

Parameter Value range

Standard value Description

"k-factor Negative Sequence"

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

"Static Threshold"

0 ‑ 10 2.0 Multiplication factor (k-

factor) for the negativesequence 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 symmetrical supply is required, this is set to 0.

Standard value Description

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.

Parameter Value range

"Static Detection Mode"

Voltage system used for

L-N Voltage L-N Voltage The phase-to-neutral (line-

L-L Voltage The phase-to-phase (line-

Standard value Description

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.

to-neutral) voltage system is used for static threshold detection of VFRT Region

to-line) voltage system is used for static threshold detection of VFRT Region

L-L and L-N Voltage

Both voltage systems

(line-to-neutral and lineto-line) are used for static threshold detection of VFRT Region 3.

Parameter Value range

Standard value Description

"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 cur-

rent and reactive current is maintained for as long as the fault persists.

Zero Current Zero Cur-

rent

Active Symmetric Current

A symmetrical reactive

The alternating current is adjusted to zero. There is no effective or reactive power feed-in during the fault.

current (positive-sequence system reactive current) is fed into the grid. The amount of the additional reactive current results from the "k-factor Posit-

ive Sequence" multiplied

by the amount of the voltage dip. No active current is fed in.

"k-factor Positive Sequence"

Active Asymmetric Current

0 ‑ 10 2.0 Multiplication factor (k-

An additional reactive cur-

"k-factor Negative Sequence" is set to 0, the

feed is symmetrical. Otherwise, asymmetrical faults are responded to with an asymmetrical current in-feed.

factor) for the positive-sequence system reactive current in Region 3. Only applied with current inrush mode "Active Sym-

metric Current" and "Active Asymmetric Current".

Parameter Value range

"k-factor Negative Sequence"

Active Power 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.

0 ‑ 10 2.0 Multiplication factor (k-

Standard value Description

factor) for the negativesequence 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 symmetrical supply is required, this is set to 0.

When the function is activated and the specified grid 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 ex-

ample "System with storage and active grid support enabled" - blue charac-

teristic 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 Hys-

teresis) No battery in the system

"Active Grid Support": Off

"Calculation Mode": P

= Pm‑Pn(k*df)

max

(1) Momentary effective power when the

"Activation Threshold Overvoltage" is

reached: 50 % of Pn (equipment nominal power)

(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 Hys-

teresis) Battery is active

"Active Grid Support": Off

"Calculation Mode": P

= Pm‑Pn(k*df)

max

(1) (4) Momentary effective power when the

respective "Activation Threshold" is reached: 50 % of Pn (equipment -

nominal power)

(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 Hys-

teresis) Battery is active

"Active Grid Support": On

"Calculation Mode": P

= Pm‑Pn(k*df)

max

(1) (4) Momentary effective power when the

respective "Activation Threshold" is

reached: 50 % of Pn (equipment -

nominal power) (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 grid 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 deactiv-

ated.

On (without

The function is activated.

Hysteresis)

"Activation Threshold Overvoltage"

"Gradient Overvoltage"

208 ‑ 311 [V] Mains voltage limit value

above which the power reduction takes place.

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

Parameter Value range Description Availability

"Calculation Mode"

"Active Grid Support"

max

Pm-Pm(k*dV)

Indicates the reference power for calculating the power limit in the event of

max

Pn-Pn(k*dV)

max

Pm-Pn(k*dV)

overvoltage or undervoltage.

Reference power:

Pm → Momentary

power when the mains voltage limit value is exceeded. Pn → Nominal power

of the device.

Off Deactivates extended act-

ive mains support for devices with a battery.

On Activates extended active

mains 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

"Activation Threshold Undervoltage"

"Gradient Undervoltage"

"Time Constant (τ)"

0 ‑ 311 [V] Mains voltage limit value

above which the power increase takes place.

0 ‑ 100 [%/V] Gradient by which the ef-

fective power increases.

Example - conversion from static to gradient: Static s = 4 % → Gradient k = 1/(0.04*230 V) =

10.9 %/V

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)

Parameter Value range Description Availability

"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 func-

tion.

"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 hys-

teresis)

(1) "Activation Threshold Overvoltage":

250 V

(2) "Stop at Voltage at Overvoltage":

260 V

(3) "Power at Stop Voltage - Over-

voltage": 20 %

Used exclusively in the following setups:

AUS

Region A 2020 AUS

Region B 2020 AUS

Region C 2020 NZS

2020

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 "Ac-

tivation Threshold Undervoltage" and "Power at Stop Voltage at Undervoltage". The parameters "Gradient Undervoltage"

and "Calculation Mode" have no function.

"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 hys-

teresis)

(1) "Activation Threshold Undervoltage":

210 V

(2) "Stop at Voltage at Undervoltage":

200 V

(3) "Power at Stop Voltage - Under-

voltage": 20 %

Used exclusively in the following setups:

AUS

Region A 2020 AUS

Region B 2020 AUS

Region C 2020 NZS

2020

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 grid frequency. A distinction is made between:

Overfrequency

Underfrequency

When the function is activated and the specified grid 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

power 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 to 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 underfre-

quency 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 grid frequency falls within the permitted frequency range again following successful power reduction, 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 Under-

frequency": P

max

= Pm-

Pn(k*df)

"Calculation Mode Over-

frequency": P

max

= Pm-

Pn(k*df)

(1) Momentary effective power when the

respective "Activation Threshold" is reached: 60 % of Pn (nominal power).

(2) "Gradient Underfrequency": 80 %/Hz

- Increase of output power without battery only possible if sufficient power from PV generator is available and manual power limitation is active. For this purpose, the "Priority at Un-

derfrequency" parameter must be set

to "Priority on Frequency-dependent

Power Limitation".

(3) "Activation Threshold Underfre-

quency": 49.7 Hz

(4) "Gradient Overfrequency": 60%/Hz (5) "Activation Threshold Overfre-

quency": 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 Pn (nominal power).

(2) "Activation Threshold Underfre-

quency": 49.7 Hz

(3) "Stop Frequency - Underfrequency":

49.0 Hz

(4) "Power at Stop Frequency - Underfre-

quency": 85 %

(5) "Activation Threshold Overfre-

quency": 50.3 Hz

(6) "Stop Frequency - Overfrequency":

51.3 Hz

(7) "Power at Stop Frequency - Overfre-

quency": 20 %

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

Example 3 Description of the parameter

"P(f) Mode": On (with Hys-

teresis)

"Configuration Method":

Gradient

"Active Grid Support": Off

"Calculation Mode Under-

frequency": P

max

= Pm-

Pn(k*df)

"Calculation Mode Over-

frequency": P

max

= Pm-

Pn(k*df)

(1) Momentary effective power when the

respective "Activation Threshold" is reached: 60 % of Pn (nominal power).

(2) "Gradient Underfrequency": 80 %/Hz (3) "Activation Threshold Underfre-

quency": 49.7 Hz

(4) "Lower Deactivation Threshold Un-

derfrequency": 49.9 Hz

(5) "Upper Deactivation Threshold Un-

derfrequency": 50.1 Hz

(6) "Gradient Overfrequency": 60 %/Hz (7) "Activation Threshold Overfre-

quency": 50.3 Hz

(8) "Lower Deactivation Threshold Over-

frequency": 49.9 Hz

(9) "Upper Deactivation Threshold Over-

frequency": 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"

"Configuration Method"

Off The function is deactiv-

ated.

On (with Hysteresis)

On (without Hysteresis)

Gradient For calculating the power

Function is activated with hysteresis.

Function is activated without hysteresis.

limitation depending on the parameters "Gradient

Overfrequency" or "Gradient Underfrequency".

In the following setups "On

(without Hysteresis)"

is not possible:

AUS

Region A 2020 AUS

Region B 2020 AUS

Region C 2020 NZS

2020

"Active Grid Support"

Stop - Frequency

Off Deactivates extended act-

On Activates extended active

The gradient is calculated automatically using the parameters "Stop Fre-

quency - Overfrequency"

and "Power at Stop Fre-

quency - Overfrequency"

as well as "Stop Fre-

quency - Underfrequency"

and "Power at Stop Fre-

quency - Underfrequency".

ive mains support for devices with a battery.

mains 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

Overfrequency

Parameter Value range Description Availability

"Calculation Mode Overfrequency"

"Activation Threshold Overfrequency"

"Gradient Overfrequency"

max

Pm-Pm(k*df)

Indicates the reference power for calculating the power limit in the event of

max

overfrequency.

Pn-Pn(k*df)

max

Pm-Pn(k*df)

Reference power

Pm → Momentary

power when the frequency limit value is exceeded. Pn → Nominal power

of the device.

45 ‑ 66 [Hz] Frequency limit value

above which the power reduction takes place.

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"

"Power at Stop Frequency Overfrequency"

"Upper Deactivation Threshold Overfrequency"

45 ‑ 66 [Hz] Frequency value at which

the power reduction ends.

-100 ‑ 0 [%] Power when the set frequency limit value "Stop

Frequency - Overfrequency" is reached. Ad-

justable between 0 % and full charging power (-100 %).

45 ‑ 66 [Hz] In use if "Mode" - "On

(with Hysteresis)" is set.

If the grid frequency falls below this value, the frequency-dependent power reduction is terminated, taking into account the settings under "Fre-

quency-dependent Power Control - General".

Parameter Value range Description Availability

"Lower Deactivation Threshold Overfrequency"

"Transition Frequency at Overfrequency"

45 ‑ 66 [Hz] Used when "Mode" is set

to "On (with Hysteresis)". If this value is less than the "Upper Deactivation

Threshold Overfrequency", a frequency win-

dow results in which the grid 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.

45 ‑ 66 [Hz] Frequency at which the

device with active battery reaches an output power of 0 W. If the grid 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 (behaviour 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 Hys-

teresis)

"Active Grid Support": On

Battery is active

(1) Momentary effective power when the

respective "Activation Threshold" is reached: 60 % of Pn (nominal power).

(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 Overfre-

quency": 50.25 Hz

(4) "Transition Frequency at Overfre-

quency": 50.75 Hz

(5) The gradient for increasing the char-

ging 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 Over-

frequency": 50.0 Hz - When the grid

frequency returns to or below the set limit value, the effective power may be increased again.

(8) "Deactivation Time": 20 s - The fre-

quency 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"

max

Pm-Pm(k*df)

max

Pn-Pn(k*df)

max

Pm-Pn(k*df)

Indicates the reference power for calculating the power limit in the event of underfrequency.

Reference power

Pm → Momentary

power when the frequency limit value is exceeded. Pn → Nominal power

of the device.

"Activation Threshold Underfrequency"

"Gradient Underfrequency"

45 ‑ 66 [Hz] Frequency limit value

above which the power increase takes place.

0 ‑ 100 [%/Hz] Gradient by which the ef-

fective 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.

Parameter Value range Description Availability

"Power at Stop Frequency - Underfrequency"

"Upper Deactivation Threshold Underfrequency"

"Lower Deactivation Threshold Underfrequency"

0 ‑ 100 [%] Power when the set fre-

quency limit value "Stop

Frequency - Underfrequency" is reached. Ad-

justable between 0 % and full feed-in power (100 %).

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 fre-

quency window in which the grid 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.

45 ‑ 66 [Hz] In use when "Mode" - "On

(with Hysteresis)" is set.

If the grid frequency exceeds this value, the function is terminated, taking into account the settings under "Frequency-de-

pendent 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 grid 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 (behaviour 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 Hys-

teresis)

"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 Pn (nominal power)

(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 Underfre-

quency": 49.75 Hz

(4) "Transition Frequency at Underfre-

quency": 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 power of the inverter). The parameter "Power at Stop Fre-

quency - Underfrequency" has no

function in these countries.

(6) "Stop Frequency - Underfrequency":

48.0 Hz

(7) "Lower Deactivation Threshold Un-

derfrequency": 50.0 Hz - When the

grid 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 fre-

quency 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"

"Return Gradient 1 Alternative"

0.01 ‑ 100 [%/s]Rate of change at which the inverter increases the effective power after the limitation has ended.

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".

Parameter Value range Description Availability

"Return Gradient 1 Alternative Threshold"

0 ‑ 100 [W%] Threshold value from

which "Return Gradient 1" or "Return Gradient 1 Al-

ternative" 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 ap-

plied.

Example 6 Description of the parameter

Actual power at the moment the limit

value is exceeded

Reduced power

red

(1) "Gradient Overfrequency" (2) "Deactivation Time" (3) "Return Gradient 1" (4) "Return Gradient 1 Alternative" (5) "Return Gradient 1 Alternative

Threshold": Pm - P

<= 25 %

red

(6) "Return Gradient 1 Alternative

Threshold": Pm - P

> 25 %

red

(7) "Intentional Delay"

The grid frequency returns to the permissible range at P

red

After the waiting time (2) has elapsed, the power is increased to the initial value Pm with

one of the following gradients:

Gradient 1 - red

The difference between the current power Pm and the reduced power P

is ≤ "Return

red

Gradient 1 Alternative Threshold" of 25 %

(5). Thus, the power is increased to the initial value Pm with "Return Gradient 1" (3).

Gradient 2 - grey

The difference between the current power Pm and the reduced power P

is > "Return

red

Gradient 1 Alternative Threshold" of 25 %

(5). This increases the power to the output value Pm with "Return Gradient 1 Alternat-

ive" (4).

Application example with "Return Gradient 1 Alternative" and "Return Gradient 1 Alternative

Threshold".

Parameter Value range Description Availability

"Return Gradient 2 Mode"

"Return Gradient 2"

Off Deactivates the use of

"Return Gradient 2". Rais-

ing the effective power from the reduced value to the device rated output takes place according to

"Return Gradient 1".

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".

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

Actual power at the moment the limit

value is exceeded

Reduced power

red

(1) "Gradient Overfrequency" (2) "Deactivation Time" (3) "Return Gradient 1" (4) "Return Gradient 2" (5) "Intentional Delay"

At P

the grid frequency returns to the per-

red

missible range. After the end of the waiting time (2), the power is increased to the initial value Pm with "Return Gradient 1". The

power is then increased to the device nominal output Pn with "Return Gradient 2" (4).

Application example with "Return Gradient 2 Mode".

Parameter Value range Description Availability

"Deactivation Time"

"Intentional Delay"

"Time Constant (τ)"

0 ‑ 600 [s] Used when "Mode" is set

to "On (with Hysteresis)". Waiting time after which the inverter increases the power again (after the grid frequency is again within the permitted frequency range between "Upper De-

activation Threshold" and "Lower Deactivation Threshold").

0.5 ‑ 60 [s] Delays the start of the frequency-dependent power control after exceeding the respective "Activation

Threshold".

0 ‑ 60 [s] Time constant (1 Tau) in

Battery SoC Limitation for Grid Support

Parameter Value range Description Availability

"Mode" Off Deactivated SoC limitation

On Activated SoC limitation

"Battery SoC Lower Limit"

"Battery SoC Upper Limit"

General - Active Power

Parameter Value range Description Availability

"Priority at Underfrequency"

0 ‑ 100 % The battery is not further

discharged when the lower limit is reached.

0 ‑ 100 % The battery is no longer

charged when the upper limit is reached.

Priority on Manual Power Limitation

Priority on Frequency-dependent Power Limitation

With "Priority on Manual

Power Limitation" the

power is not increased above the set limit in case of underfrequency.

With "Priority on Fre-

quency-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.

Reactive Power The voltage in the national grid can be inﬂuenced by the controlled use of react-

ive 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 Sn (and the maximum output current) as well as by the operational reactive power limits of

the inverter:

Primo GEN24: Q

Symo GEN24: Q

Tauro: Q

= 100 % of Sn (or cos φ = 0.00)

max

= 60 % of Sn (or cos φ = 0.80 at Sn)

max

= 71 % of Sn (or cos φ = 0.70 at Sn)

max

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

"Mode"

Range of values Description

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

Q Absolute Constant Reactive Power

Q Relative Constant Reactive Power

Cos φ(P) Power dependent Power Factor Characteristic

Q(P) - Power dependent Reactive Power Characteristic

Constant Cos φ.

Constant reactive power in [Var].

Constant reactive power in percent [%] of Sn.

Effective power-dependent Cos φ control.

Effective power-dependent reactive power control.

"P/Q Priority"

"Cos φ Minimum"

Q(U) - Voltage dependent Reactive Power Characteristic

Q Priority When the maximum apparent power is

P Priority The setting "P Priority" leads to a reduc-

0 ‑ 1 Minimum cos φ, which together with the

Mains voltage dependent reactive power control.

reached, the setting "Q Priority" leads to a reduction of the effective power in favour of reaching the reactive power specification.

tion of the reactive power in favour of reaching the available effective power when the maximum apparent power is reached.

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.

Range of val-

Parameter

ues Description

"cos φ - Power Factor"

"Direction / Excitation"

"Time Constant (τ)"

0 ‑ 1 Set value of Cos φ

The current direction corresponds to the

generator counter arrow system.

Over-Excited Over-excited operation = capacitive opera-

tion = reactive power is supplied = reactive current is fed in lagging the active current.

Under-Excited Under-excited operation = inductive oper-

ation = reactive power is drawn = reactive current is fed in ahead of the active current.

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"

Range of val-

Parameter

ues Description

"Q - Reactive Power (Var)"

"Time Constant (τ)"

-200,000 Var -

200,000 Var

0.01 s ‑ 60 s Time constant (1 Tau) in seconds [s].

Reactive power setting value in [Var] (set value)

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 (Sn) of the inverter. The function is limited by the maximum apparent power and by "Cos φ Minimum".

Range of val-

Parameter

ues Description

"Q - Reactive Power (% of Nominal Apparent Power)"

"Time Constant (τ)"

-100 % -

100 %

0.01 s ‑ 60 s Time constant (1 Tau) in seconds [s].

Reactive power setting as a percentage [%] in relation to the nominal apparent power (set value)

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).

Range of val-

Point Parameter

ues Description

"Active Power (% of Nominal Apparent Power)"

"cos φ - Power Factor"

"Direction / Excitation"

Under-Excited Under-excited operation = in-

"Active Power (% of Nominal Apparent Power)"

"cos φ - Power Factor"

"Direction / Excitation"

0 % ‑ 100 % Effective power in percent

[%] related to the nominal apparent power Sn.

0 ‑ 1 Set value of Cos φ.

The current direction corres-

ponds to the generator counter arrow system.

ductive operation = reactive power is drawn = reactive current is fed in ahead of the active current.

Over-Excited Over-excited operation = ca-

pacitive operation = reactive power is supplied = reactive current is fed in lagging the active current.

0 % ‑ 100 % Effective power in percent

[%] related to the nominal apparent power SN.

0 ‑ 1 Set value of Cos φ.

The current direction corres-

ponds to the generator counter arrow system.

Under-Excited Under-excited operation = in-

ductive operation = reactive power is drawn = reactive current is fed in ahead of the active current.

Over-Excited Over-excited operation = ca-

pacitive operation = reactive power is supplied = reactive current is fed in lagging the active current.

Point Parameter

Range of values Description

"Active Power (% of Nominal Apparent Power)"

"cos φ - Power Factor"

"Direction / Excitation"

"Active Power (% of Nominal Apparent Power)"

"cos φ - Power Factor"

"Direction / Excitation"

0 % ‑ 100 % Effective power in percent

[%] related to the nominal apparent power SN.

0 ‑ 1 Set value of Cos φ.

The current direction corres-

ponds to the generator counter arrow system.

Under-Excited Under-excited operation = in-

ductive operation = reactive power is drawn = reactive current is fed in ahead of the active current.

Over-Excited Over-excited operation = ca-

pacitive operation = reactive power is supplied = reactive current is fed in lagging the active current.

0 % ‑ 100 % Effective power in percent

[%] related to the nominal apparent power SN.

0 ‑ 1 Set value of Cos φ.

The current direction corres-

ponds to the generator counter arrow system.

Under-Excited Under-excited operation = in-

ductive operation = reactive power is drawn = reactive current is fed in ahead of the active current.

Over-Excited Over-excited operation = ca-

pacitive 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

"Lock-In Voltage-Dependent (% of Nominal Voltage)"

"Lock-Out Voltage-Dependent (% of Nominal Voltage)"

Range of values Description

0 % ‑ 120 % AC voltage in per-

cent [%] related to the nominal voltage. If this value is exceeded, the Cos φ(P) characteristic is activated.

0 % ‑ 120 % AC voltage in per-

cent [%] related to the nominal voltage. If this value is undershot, the Cos φ(P) characteristic is deactivated. The lockout limit has priority over the lock-in limit.

Supplementary description

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 (LockIn) 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.

Parameter

Range of values Description

Supplementary description

"Lock-Out PDependent (% of Nominal Apparent Power)"

"Time Constant (τ)"

0 % ‑ 100 % Effective power in

percent [%] related to the nominal apparent power SN. If

this value is undershot, the Cos φ(P) characteristic is deactivated.

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)

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.

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.

Range of val-

Point Parameter

ues Description

"Active Power (% of Nominal Apparent

0 % ‑ 100 % Effective power in percent

[%] related to the nominal apparent power Sn (X‑axis).

Power)"

"Reactive Power (% of Nominal Apparent

-100 % ‑ 100 % Reactive power in percent [%] related to the nominal apparent power Sn (Y‑axis).

Power)"

"Active Power (% of Nominal Apparent

0 % ‑ 100 % Effective power in percent

[%] related to the nominal apparent power Sn (X‑axis).

Power)"

"Reactive Power (% of Nominal Appar-

-100 % ‑ 100 % Reactive power in percent [%] related to the nominal apparent power Sn (Y‑axis).

ent Power)"

"Active Power (% of Nominal Apparent

0 % ‑ 100 % Effective power in percent

[%] related to the nominal apparent power Sn.

Power)"

"Reactive Power (% of Nominal Appar-

-100 % ‑ 100 % Reactive power in percent [%] related to the nominal apparent power Sn (Y‑axis).

ent Power)"

"Active Power

0 % ‑ 100 % Effective power in percent

(% of Nominal Apparent Power)"

"Reactive

-100 % ‑ 100 % Reactive power in percent [%]

Power (% of Nominal Apparent Power)"

Example: Curve defined by four data points.

[%] related to the nominal apparent power Sn (X‑axis).

related to the nominal apparent power Sn (Y‑axis).

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

"Lock-In Voltage-Dependent (% of Nominal Voltage)"

"Lock-Out Voltage-Dependent (% of Nominal Voltage)"

"Lock-Out PDependent (% of Nominal Apparent Power)"

Range of values Description

0 % ‑ 120 % AC voltage in per-

cent [%] related to the nominal voltage. If this value is exceeded, the Q(P) characteristic is activated.

0 % ‑ 120 % AC voltage in per-

cent [%] related to 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.

0 % ‑ 100 % Effective power in

percent [%] related to the nominal apparent power SN. If

this value is undershot, the Q(P) characteristic is deactivated.

Supplementary description

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 (LockIn) 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.

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.

Range of val-

Parameter

"Time Constant (τ)"

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.

ues Description

Supplementary description

Point Parameter

1 "Voltage (% of

Nominal Voltage)"

"Reactive Power (% of Nominal Apparent Power)"

"Voltage (% of Nominal Voltage)"

"Reactive Power (% of Nominal Apparent Power)"

"Voltage (% of Nominal Voltage)"

"Reactive Power (% of Nominal Apparent Power)"

Range of values Description

50 % ‑ 150 % AC voltage in percent [%] re-

lated to the nominal voltage (X‑axis).

-100 % ‑ 100 % Reactive power in percent [%] related to the nominal apparent power Sn (Y‑axis).

50 % ‑ 150 % AC voltage in percent [%] re-

lated to the nominal voltage (X‑axis).

-100 % ‑ 100 % Reactive power in percent [%] related to the nominal apparent power Sn (Y‑axis).

50 % ‑ 150 % AC voltage in percent [%] re-

lated to the nominal voltage (X‑axis).

-100 % ‑ 100 % Reactive power in percent [%] related to the nominal apparent power Sn (Y‑axis).

Point Parameter

Range of values Description

General

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

Parameter

"Offset Factor" -1 ‑ 1 Shift of the Q(U)

"Voltage (% of Nominal Voltage)"

"Reactive Power (% of Nominal Apparent Power)"

Range of values Description

50 % ‑ 150 % AC voltage in percent [%] re-

-100 % ‑ 100 % Reactive power in percent [%]

lated to the nominal voltage (X‑axis).

related to the nominal apparent power Sn (Y‑axis).

Supplementary description

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"

"Lock-In P-Dependent (% of Nominal Apparent Power)"

"Lock-Out PDependent (% of Nominal Apparent Power)"

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.

0 % ‑ 120 % Effective power in

percent [%] related to the nominal apparent power Sn. If

this value is exceeded, the Q(P) characteristic is activated.

0 % ‑ 100% Effective power in

percent [%] related to the nominal apparent power SN. If

this value is undershot, the Q(P) characteristic is deactivated. The lock-out limit has priority over the lock-in limit.

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 (LockIn) 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.

Parameter

"Time Constant (τ)"

Range of values Description

Supplementary description

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

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

Example: Curve defined by four data points.

Fronius GEN24 and Tauro Country Setup Menu Operating Instruction [EN]

Specifications and Main Features

Frequently Asked Questions

User Manual