Service Menü - SnapINverter Service Manual

The "Service menus" are setup menus for installers and service engineers. The "Service menus" are located at a separate menu level that can only be opened by entering an access code.
The access code is provided by Fronius.

The following "Service menus" are described in these instructions:

Service Basic menu
Service Error Counter menu
Service Pro menu

The "Service menus" are setup menus for installers and service engineers. The "Service menus" are located at a separate menu level that can only be opened by entering an access code.
The access code is provided by Fronius.

The following "Service menus" are described in these instructions:

Service Basic menu
Service Error Counter menu
Service Pro menu

CAUTION!

Incorrect settings can cause malfunctions and failures on the inverter.

Settings may only be made by trained and qualified personnel. Incorrect or omitted settings will result in non-conformance with the standard.

IMPORTANT! If a status code is shown on the inverter display during the startup phase, the "Service menus" can be opened by pressing the "Menu" button five times and then entering the relevant access code.

Refer to the safety rules in the inverter Operating Instructions.

The functions described in these instructions are valid from the following firmware versions:

SnapINverter ROW: fro29390.upd and higher
SnapINverter US: fro29390.upd and higher

1Press the "Menu" key

until the screen on the left appearsThe menu level appears

2Press the unassigned "Menu / Esc" key 5 times

"Access Code" is displayed in the "CODE" menu; the first digit starts flashing

3Enter the access code for the Service menu required: Use keys

to select a value for the first digit of the code

4Press "Enter"

The second digit flashes

5Repeat steps 3 and 4 for the second, third, fourth and fifth digits of the access code until...

... the selected code starts flashing.

6Press "Enter"

12345 ... Example codeThe first parameter of the required Service menu is displayed

1Press the "Menu" key

until the screen on the left appearsThe menu level appears

2Press the unassigned "Menu / Esc" key 5 times

"Access Code" is displayed in the "CODE" menu; the first digit starts flashing

3Enter the access code for the Service menu required: Use keys

to select a value for the first digit of the code

4Press "Enter"

The second digit flashes

5Repeat steps 3 and 4 for the second, third, fourth and fifth digits of the access code until...

... the selected code starts flashing.

6Press "Enter"

12345 ... Example codeThe first parameter of the required Service menu is displayed

1Open the desired menu

2Use the 'Up' or 'Down' keys to select the desired menu item

3Press "Enter"

The available settings are displayed:		The first digit of a value to be set flashes:
4Use the 'Up' or 'Down' buttons to select the desired setting 5Press the 'Enter' key to save and apply the setting. To discard the setting, press the 'Esc' key.		4Use the 'Up' or 'Down' keys to select a value for the first digit 5Press "Enter" The second digit of the value flashes. 6Repeat steps 4 and 5 until ... the whole value to be set flashes.
		7Press "Enter" 8Repeat steps 4 - 6 as required for units or other values that are to be set until the appropriate unit or the value flashes. 9Press the 'Enter' key to save and apply the changes. To discard the changes, press the 'Esc' key.
The currently selected menu item is displayed.		The currently selected menu item is displayed.

2 2 7 4 2

1)	The value is applied
2)	The function is deactivated
3)	Apply the function settings as described in the inverter Operating Instructions
4)	Max. and min. voltage values and max. power of feeding in are reset to zero in the TOTAL display mode

^a	Fronius Galvo	^h	Fronius Eco
^b	Fronius Symo 3.0 - 4.5 S	ⁱ	Fronius Symo 10.0 - 12.0 208-240
^c	Fronius Symo 3.0 - 8.2 M	^j	Fronius Symo 10.0 - 24.0 480
^d	Fronius Symo 10.0 - 20.0 M	^k	Fronius Symo 15.0 208
^e	Fronius Symo Hybrid	^l	Fronius Primo 3.8 - 8.2 (UL version)
^f	Fronius Primo 3.0 - 8.2	^m	Fronius Symo Advanced 10.0 - 12.0 208-240
^g	Fronius Primo 10.0 - 15.0 (UL version)	ⁿ	Fronius Symo Advanced 15.0 - 24.0 480

MPP Tracker 1	DC operating mode	MPP AUTO
		FIX
		MPP USER
	Dyn. Peak Manager ^{b,c,d,e,f,g,h,i,j,k,l}	ON OFF	2)
	Fixed voltage	80 - 800 V ^f,g,l 120 - 440 V ^a 150 - 800 V ^b,c,d,e,i,j 325 - 850 V ^k 580 - 850 V ^h	1) 1) 1) 1) 1)
	MPPT1 start voltage	80 - 800 V ^f,g,l 120 - 440 V ^a 150 - 800 V ^b,c,d,e,i,j 325 - 850 V ^k 580 - 850 V ^h	1) 1) 1) 1) 1)
MPP Tracker 2 ^{c,d,f,g,i,j,l}	MPP Tracker 2	ON OFF	2)
	DC operating mode	MPP AUTO
		FIX
		MPP USER
	Dyn. Peak Manager	ON OFF	2)
	Fixed voltage	80 - 800 V ^f,g,l 150 - 800 V ^c,d,i,j,	1) 1)
	MPPT2 start voltage	80 - 800 V ^f,g,l 150 - 800 V ^c,d,i,j,	1) 1)
USB logbook	ON
	OFF		2)
	Auto		2)
Input signal	Mode of operation	Ext Sig. S0-Meter OFF	2)
	Triggering method (indicated by selection of "Ext Sig.")	Ext. Stop Warning
	Connection type (indicated by selection of "Ext Sig.")	N/C N/O
	Grid power limit	0 - Device rated power	1)
	Impulse rate	100 - 20000	1)
SMS / relay	Event delay	900 - 86,400 s	1)
	Event counter	10 - 255	1)
Grounding setting ^{Fronius Galvo}	Grounding mode	OFF Positive Negative	2)
	Earth current watchdog	Warning Error Warn Err
	Switch-off delay	0 - 9999 hrs	1)
Insulation mode ^{b,c, d,e,f,g,h,i,j,k,l}	Insulation warning	ON OFF	2)
	Threshold warning	0.1 - 10 MOhm ^b,c,d,e,h 0.5 - 10 MOhm ^k 0.6 - 10 MOhm ^a,g,i,j 1 - 10 MOhm ^f,l	1) 1) 1) 1)
	Threshold error	600 kOhm - 10,000 kOhm	1)
TOTAL reset	CONFIRM		4)

The display of menu items depends on the respective country setup.

Setting the operating mode of MPP Tracker 1

Selection options

DC operating mode / Dyn. Peak Manager / Fixed voltage / MPPT1 start voltage

	DC operating mode to adjust how the Maximum Power Point (MPP) Tracker should work
	Selection options	MPP AUTO / FIX / MPP USER
	MPP AUTO	normal operating status; the inverter automatically searches for the ideal operating point across the complete MPP operating range (if the PV voltage falls below the preset value, the inverter will shut down with STATE 306 (PV output too low))
	FIX	for entering a fixed DC voltage at which the inverter will operate
	MPP USER	for entering the start voltage, at which the MPP tracker starts searching for the optimal operating point.
	Dyn. Peak Manager for activating or deactivating the Dynamic Peak Manager
	Selection options	ON / OFF
	Fixed voltage for entering the fixed voltage
	Unit	V
	Setting range	80 - 800 ^f,g,l 120 - 440^a 150 - 800^b,c,d,e,i,j 325 - 850^k 580 - 850^h
	MPPT1 start voltage for entering the MPPT1 start voltage
	Unit	V
	Setting range	80 - 800 ^f,g,l 120 - 440^a 150 - 800^b,c,d,e,i,j 325 - 850^k 580 - 850^h

Setting the operating mode of the MPP Tracker 2

Selection options

MPP Tracker 2 / DC operating mode / Dyn. Peak Manager / Fixed voltage / MPPT2 start voltage

	MPP Tracker 2 for activating/deactivating a 2nd MPP tracker
	Setting range	OFF/ ON
	DC operating mode
	Selection options	MPP AUTO / FIX / MPP USER
	MPP AUTO	normal operating status; the inverter automatically searches for the ideal operating point across the complete operating range (if the voltage falls below the preset value, the inverter will shut down with STATE 306 (PV output too low))
	FIX	for entering a fixed DC voltage at which the inverter will operate
	MPP USER	for entering the MPP voltage above which the inverter will search for its ideal operating point
	Dyn. Peak Manager for activating or deactivating the Dynamic Peak Manager
	Selection options	ON / OFF
	Fixed voltage fixed voltage value limits according to power stage set. The value assigned here is assumed for MPP1 and MPP 2
	Unit	V
	Setting range	Fronius Primo: 80 - 800 Fronius Symo (except Fronius Symo 3.0 - 4.5 S): 150 - 800
	MPPT2 start voltage for entering the MPPT2 start voltage
	Unit	V
	Setting range	80 - 800 150 - 800

Activates or deactivates the function for saving to the USB flash drive all occurring status codes, as well as all inverter data, in 5 second values. This data will be saved on the USB flash drive in the EVENT.csv file.

Selection options

ON / OFF / Auto

The "Auto" setting is reserved for future USB modifications and currently has a similar function to the "OFF" setting.

Activation and setting of the Input signal at the multifunction current interface

Selection options

How it works / Triggering method / Connection type / Grid feed-in limit / Pulses per kWh
(Triggering method and Connection type only visible by selecting "Ext Sig.")

	How it works
	Ext Sig.	Signal input (e.g. signal contact for the surge protection device)
	S0-Meter	Counting the pulses of an external S0 meter (input)
	OFF	Mode of operation deactivated
	Triggering method
	Ext. Stop	In the event of a signal error, an external stop appears on the display (State 668 - interruption of feed-in).
	Warning	In the event of a signal error, a warning appears on the display at regular intervals (State 568 - multifunction current interface warning, no interruption of feed-in).
	Connection type
	N/C	Normally-closed function (n.c. = normally closed)
	N/O	Normally-open function (n.o. = normally open)
	Grid feed-in limit
	Field for entering the maximum amount of energy to be fed into the grid in W. If this value is exceeded, the inverter regulates down to the set value within the time required by national standards and regulations.
	Setting range	0 - Device rated power
	Pulses per kWh
	Field for entering the pulses per kWh of the S0 meter.
	Setting range	100 - 20,000

	Selection options	Event delay / Event counter
	Event delay for entering the time delay after which an SMS is sent or the relay is to switch
	Unit	s
	Setting range	900 - 86400
	Event counter for entering the number of errors after which an SMS is sent or the relay is to switch
	Unit	-
	Setting range	10 - 255

Activation and setting of the solar module ground

Selection options

Grounding mode / Earth current watchdog⁽¹⁾/ Switch off delay⁽²⁾

(1)	only displayed if "Positive" or "Negative" is selected under Grounding mode
(2)	only displayed if "Warn Err" is activated

Grounding mode
for selecting the solar module ground or deactivating this function

Selection options

Off / Positive / Negative

Earth current watchdog
for activating and deactivating the grounding monitoring

Selection options

Off / Warning / Error / Warn Err

Warning

If there is a grounding fault, a warning that there is no longer a grounding connection appears on the display at regular intervals (no interruption of feed-in). State 502 will subsequently be displayed.

Error

The inverter produces an error message if there is a grounding fault with immediate shutdown of the inverter (State 475).

Warn Err

If there is a grounding fault, a warning that there is no longer a grounding connection first appears on the display at regular intervals (no interruption of feed-in).
The inverter will then be switched off after a specified interval (switch off delay). Depending on the selected switch-off delay, STATE 551 is displayed. Once this delay time has passed, the error STATE 471 will be displayed

Switch off delay
for setting the delay time (in h) until the inverter will switch off following a grounding fault (unless the fault is rectified in the meantime).

Unit

h

Setting range

0 - 9999

IMPORTANT! If the solar module manufacturer has specified that grounding of the solar modules is required, the relevant solar module ground setting must be applied to the inverter. Instructions from the solar module manufacturer on polarity and the required solar module grounding method, as well as national regulations, must be observed.
The solar module can be grounded to the negative pole in the inverter itself. In this case use of a ground fuse (1 A) is mandatory.

IMPORTANT! The fuse in the inverter is not used for grounding the solar modules to the positive pole; this has to take place outside the inverter.

Activation and setting of the insulation settings

	Selection options	Warning mode / Warning threshold / Error threshold
	Warning mode for activating and deactivating the insulation monitoring, with display of a warning without interruption of feed-in if there is an insulation fault
	Selection options	ON / OFF
	Warning threshold for setting an insulation threshold at which the inverter produces a warning (without interruption of feed-in)
	Setting range	0.1 - 10 ^b,c,d,e,h 0.5 - 10 ^k 0.6 - 10 ^a,g,i,j 1.0 - 10 ^f,l
	Unit	MOhm
	Error threshold for setting an insulation threshold at which the inverter produces an error message and interrupts grid power feed operation
	Setting range	600 - 10000
	Unit	kOhm

In the LOG menu item, resets the max. and min. voltage values and the max. power of feeding in to zero.

NOTE!

Once values have been reset, this action cannot be undone.

3 7 7 6 7

State Counter 0-999
displays all status codes in numerical order

State Ranking TODAY
displays all the day's status codes according to their frequency

State Ranking L.Day (L.Day = Last Day)
displays all the last day's status codes according to their frequency

State Ranking ALL
displays all status codes according to their frequency

Counter Reset
Press "Enter" to reset the State Counter.
This will irretrievably delete all logged values.

Preconfigured network parameters depend on the country setup. The parameters have been selected to ensure that the inverter is compliant with currently applicable standards.
In special cases, a qualified electrician or Fronius Service Partner (FSP) can adapt preconfigured country-specific limit values to local grid conditions in the Service Pro menu.
The modified limit values are permanently saved by the inverter.

NOTE!

Modifying the monitoring parameters will immediately result in non-conformance of the inverter with the standards and, for this reason, may only be carried out after consulting the responsible grid operator.

To reinstate the original settings on the inverter, select the country setup again (Country Setup Menu - access code = 73887), as described in the User Information.

Preconfigured network parameters depend on the country setup. The parameters have been selected to ensure that the inverter is compliant with currently applicable standards.
In special cases, a qualified electrician or Fronius Service Partner (FSP) can adapt preconfigured country-specific limit values to local grid conditions in the Service Pro menu.
The modified limit values are permanently saved by the inverter.

NOTE!

Modifying the monitoring parameters will immediately result in non-conformance of the inverter with the standards and, for this reason, may only be carried out after consulting the responsible grid operator.

To reinstate the original settings on the inverter, select the country setup again (Country Setup Menu - access code = 73887), as described in the User Information.

The access code for the Service Pro menu is only provided to Fronius upon written request.
The relevant request form can be obtained from the national Technical Support team.

The display of menu items depends on the respective country setup.

n	Value, dependent on local grid and also partly on country setup
1)	The function is activated
2)	The value is applied
3)	The function is deactivated
6)	A characteristic is entered with 4 X points and 4 Y points

^a	Fronius Galvo	ⁱ	Fronius Symo 10.0 - 12.0 208-240
^b	Fronius Symo 3.0 - 4.5 S	^j	Fronius Symo 10.0 - 24.0 480
^c	Fronius Symo 3.0 - 8.2 M	^k	Fronius Symo 15.0 208
^d	Fronius Symo 10.0 - 20.0 M	^l	Fronius Primo 3.8 - 8.2 (UL version)
^e	Fronius Symo Hybrid	^m	Fronius Symo Advanced 10.0 - 12.0 208-240
^f	Fronius Primo 3.0 - 8.2	ⁿ	Fronius Symo Advanced 15.0 - 24.0 480
^g	Fronius Primo 10.0 - 15.0 (UL version)	^o	Fronius Galvo (UL version)
^h	Fronius Eco	^p	Fronius Symo Advanced 10.0 - 20.0

U Inner Limit Max	n [V]		2)
U IL Max TripTime	n [cyl]		2)
U Inner Limit Min	n [V]		2)
U IL Min TripTime	n [cyl]		2)
U Middle Limit Mode			2)
U Middle Limit Max	n [V]		2)
U ML Max TripTime	n [cyl]		2)
U Middle Limit Min	n [V]		2)
U ML Min TripTime	n [cyl]		2)
U Outer Limit Max	n [V]		2)
U OL Max TripTime	n [cyl]		2)
U Outer Limit Min	n [V]		2)
U OL Min TripTime	n [cyl]		2)
U Reconnect max	n [V]		2)
U Reconnect min	n [V]		2)
U Recon. IL max	n [V]		2)
U Recon. IL min	n [V]		2)
U Longtime Limit	n [V]		2)
U Fast Supervisory	ON x OFF x
Freq. Inner Limit Max	n [Hz]		2)
Freq IL Max TripTime	n [cyl]		2)
Freq. Inner Limit Min	n [Hz]		2)
Freq IL Min TripTime	n [cyl]		2)
Alt Freq Mode	ON		1)
	OFF		3)
Alt Freq IL Max	n [Hz]		2)
Alt Freq IL Max TT	n [cyl]		2)
Alt Freq IL Min	n [Hz]		2)
Alt Freq IL Min TT	n [cyl]		2)
Freq Outer Limit Max	n [Hz]		2)
Freq OL Max TripTime	n [cyl]		2)
Freq Outer Limit Min	n [Hz]		2)
Freq OL Min TripTime	n [cyl]		2)
Redundant FAC Check	ON x OFF x
Redundant UAC Check	ON x OFF x
NL-MONitor^d,i,j,k,l,o	NL-MONitor On/Off	ON x OFF x Stinger^i,j,k x	1) 3) 1)
	NL Uouter Limit Min	n [Hz]	2)
	NL U OL Min TripTime	n [cyl]	2)
	NL UMiddle Limit Min	n [Hz]	2)
	NL U ML Min TripTime	n [cyl]	2)
	NL Uinner Limit Min	n [Hz]	2)
	NL U IL Min TripTime	n [cyl]	2)
	NL Uinner Limit Max	n [Hz]	2)
	NL U IL Max TripTime	n [cyl]	2)
	NL UMiddle Limit Max	n [Hz]	2)
	NL U ML Max TripTime	n [cyl]	2)
	NL Uouter Limit Max	n [Hz]	2)
	NL U OL Max TripTime	n [cyl]	2)
Freq Reconnect max	n [Hz]		2)
Freq Reconnect min	n [Hz]		2)
Freq Recon. IL max	n [Hz]		2)
Freq Recon. IL min	n [Hz]		2)
Trip Time Delay	n [cyl]		2)
Reactive Power Mode	React. P. Mode	Cos φ / P x Q / U x Q / P x OFF x C. Cos φ x C. Qrel x C. Qabs x	1) 1) 1) 3) 1) 1) 1)
	Grid Power Priority	Reactive x Active x	1) 1)
	Const. Cos φ		2)
	Const. Cos φ TimeC.		2)
	Const. Q Rel		2)
	Const. Q Rel TimeC.		2)
	Const. Q Abs		2)
	Const. Q Abs TimeC.		2)
	Ch Cos φ (P) 0-0		6)
	Ch Cos φ (P) 0-1		6)
	Ch Cos φ (P) 1-0		6)
	Ch Cos φ (P) 1-1		6)
	Ch Cos φ (P) 2-0		6)
	Ch Cos φ (P) 2-1		6)
	Ch Cos φ (P) 3-0		6)
	Ch Cos φ (P) 3-1		6)
	Ch Cos φ (P) TimeC.		2)
	Ch Cos φ (P) U-LockIn		2)
	Ch Cos φ (P) U-LockOut		2)
	Ch Cos φ (P) P-LockOut		2)
	Ch Q (U) 0-0		6)
	Ch Q (U) 0-1		6)
	Ch Q (U) 1-0		6)
	Ch Q (U) 1-1		6)
	Ch Q (U) 2-0		6)
	Ch Q (U) 2-1		6)
	Ch Q (U) 3-0		6)
	Ch Q (U) 3-1		6)
	Ch Q (U) Init Delay		2)
	Ch Q (U) Offset Factor		2)
	Ch Q (U) TimeC.		2)
	Ch Q (U) P-LockIn		2)
	Ch Q (U) P-LockOut		2)
	Ch Q (U) Cos φ Min.		2)
	Ch Q (P) 0-0		6)
	Ch Q (P) 0-1		6)
	Ch Q (P) 1-0		6)
	Ch Q (P) 1-1		6)
	Ch Q (P) 2-0		6)
	Ch Q (P) 2-1		6)
	Ch Q (P) 3-0		6)
	Ch Q (P) 3-1		6)
	Ch Q (P) TimeC.		2)
	Ch Q (P) U-LockIn		2)
	Ch Q (P) U-LockOut		2)
	Ch Q (P) P-LockOut		2)
Freq dep. Power Red	GFDPR ON/OFF	Off x On DisHyst x On x	3) 1) 1)
	P-Reduct. Reference	Pn-Pnkx x Pm-Pnkx x Pm-Pmkx x act. Pwr. x nom. Pwr. x	3) 1) 1) 1) 1)
	P-Increa. Reference	Pn-Pnkx x Pm-Pnkx x Pm-Pmkx x	3) 1) 1)
	Enable Limit	50 - 52 Hz	2)
	Enable Limit Under F.^e)	49,7 - 49,9 Hz	2)
	Intentional Delay	0 - 60 s	2)
	Derating Gradient	0,01 - 100%/Hz	2)
	Derating Gradient U.F.^e)	0,01 - 100%/Hz	2)
	Stop Frequency	100 - 0 %
	Stop Frequency U.F.^e)	0 - 100 %
	Change Time Constant	0 - 60 s	2)
	Frequency Test Time	0 - 600 s	2)
	Disable Limit Min.	50 - 52 Hz	2)
	Disable Limit Max.	50 - 52 Hz	2)
	Alt. Ret. Grad Thr.	0,01 - 100 %	2)
	Return Gradient 1	0,01 - 100 %/s	2)
	Alt. Return Grad. 1	0,01 - 100 %/s	2)
	Use Return Grad. 2	OFF x ON x	3) 1)
	Return Gradient 2	0,01 - 100 %/s	2)
	P(f) f transition Of****	Hz	2)
	P(f) f transition Uf****	Hz	2)
Volt. dep. Power Red	GVDPR On/Off	Off x On x	3) 1)
	P-Reduct. Reference	Pn-Pnkx x Pm-Pnkx x Pm-Pmkx x	3) 1) 1)
	Enable Limit	208 - 300 V	2)
	Derating Gradient	0.01 - 100 %/V	2)
	Enable Limit UnderV.	200 - 250 V	2)
	Derating Gr. UnderV.	0.01 - 100 %/V	2)
	Change Time Constant	0.01 - 600 s	2)
	Event Message	OFF x ON x	3) 1)
	P(U) Stop Voltage OV***	0 -311 V (default: 270 V)	2)
	P(U) Stop Power OV****	0 -100 % (default: 0 %)	2)
	P(U) Stop Voltage UV***	200 -311 V (default: 270 V)	2)
	P(U) Stop Power UV****	0 -100 % (default: 0 %)	2)
Softstart	Softstart On/Off	Off x On acFlt x On x	3) 1) 1)
	Softstart Gradient	0.01 - 100 %/s	2)
Manual Power Reduct.			2)
Voltage Ride Through ^{c,d,e,f,g,h,i,j,k,l}	VRT Mode	OFF x ON x	3) 1)
	R1/R2 /R3 Calculation Mode	Nomin. B. x Bound. B. x Off x Passive x Zero Cur. x Act. UBCC x	3) 1) 1) 1) 1) 1)
	R1/R2 /R3 Detection Mode (Norm 50549)	LN-Volt. x LL-Volt. x LL+LN-Volt. x	3) 1) 1)
	R1/R2 /R3 Static Threshold	0 - 200 %	2)
	R1/R2 /R3 k-Factor positive-sequence system	0 - 10,000	2)
	R1/R2 /R3 k-Factor positive-sequence system	0 - 10,000	2)
	IacReactLim Overexc	0 - 110 %	2)
	IacReactLim Underexc	0 - 110 %	2)
	Sudden Voltage Change	OFF x ON x
	Insensitivity Range	0 - 100 %
	Deactivation Time	0 - 1000 s
DC-Injection	DC-I. InnerLimit M.	OFF x Absolute x Relative x	3) 1) 1)
	DC-I. I.L. Absolute	0 - 10 A	2)
	DC-I. I.L. Relative	0 - 10 %	2)
	DC-I. I.L. TripTime	0 - 10 s	2)
	DC-I. OuterLimit M.	OFF x Absolute x Relative x	3) 1) 1)
	DC-I. O.L. Absolute	0 - 10 A	2)
	DC-I. O.L. Relative	0 - 10 %	2)
	DC-I. O.L. TripTime	0 - 10 s	2)
Ripple Control	Ripple Ctrl. Mode	OFF x ON x	3) 1)
	Ripple Signal Frequency		2)
	Ripple Grid Inductance		2)
IΔF Compensation	IΔF Comp. Mode	OFF x ON x	3) 1)
	ΔUdc Link Voltage	0 - 200 V	2)
Anti Islanding	Sym Asym Sym OFF		2) 2) 2)
Grid Quality Factor	0.1-10		2)
RateOfChangeOfFreq	ROCOF On / Off	On x Off x	1) 3)
	ROCOF Limit
	ROCOF TripTime
Power Ramp Rate (only in Country Setup AU)	Power-Ramp-Up-Mode	On x Off x	1) 3)
	Power-Ramp-Up	0.00 -100 %/s
	Power-Ramp-Down-Mode	On x Off x	1) 3)
	Power-Ramp-Down	0.05 -75 %/s
Fail-Safe	DM FailSafe Mode	Off x Permanent x	3) 1)


	DM FailSafe Behaviou	Disconn.	1)
Initial Start Time	1 - 900 s		2)
Reconnect Time	1 - 900 s		2)
Powerline Comm. ^p	Powerline COM Mode	Off x SunSpec x	2)
Arc Fault Protection ^p	AFPE Mode	On x Off x	1) 3)
	Automatic Reconnect	-1 to 4

The display of menu items depends on the respective country setup.

Graphic illustrating the limits

IL	"Inner Limit" - inner limit value
ML	"Middle Limit" - middle limit value
OL	"Outer Limit" - outer limit value
(1)	Trip range

U Inner Limit Max
Upper inner grid voltage limit value in V

U IL Max TripTime
Trip time ^A) for exceeding the upper inner grid voltage limit value in cyl ^B)

U Inner Limit Min
Lower inner grid voltage limit value in V

U IL Min Trip Time
Trip time ^A) for falling below the lower inner grid voltage limit value in cyl ^B)

U Middle Limit Mode
0 or 1: 0 = Middle limits are deactivated, 1 = Middle limits are activated

U Middle Limit Max
Upper middle grid voltage limit in V

U ML Max Trip Time
Trip time for the upper middle grid voltage limit

U Middle Limit Min
Lower middle grid voltage limit in V

U ML Min Trip Time
Trip time for the lower middle grid voltage limit

U Outer Limit Max
Upper outer grid voltage limit value in V

U OL Max TripTime
Trip time ^A) for exceeding the upper outer grid voltage limit value in cyl ^B)

U Outer Limit Min
Lower outer grid voltage limit value in V

U OL Min Trip Time
Trip time ^A) for falling below the lower outer grid voltage limit value in cyl ^B)

U Reconnect max
Upper voltage limit value for reconnection to the public grid following disconnection due to impermissible parameter deviation
[V]

U Reconnect min
Lower voltage limit value for reconnection to the public grid following disconnection due to impermissible parameter deviation
[V]

U Recon. IL max
Upper inner voltage limit value for reconnection to the public grid following disconnection due to impermissible parameter deviation
[V]

U Recon. IL min
Lower inner voltage limit value for reconnection to the public grid following disconnection due to impermissible parameter deviation
[V]

U Longtime Limit
Voltage limit value in V for the 10-minute average voltage value

U Fast Supervisory
Fast surge protection cut-out, which can take place within a period.

^A)	Different trip times can be assigned to the inner limit value IL and outer limit value OL. For example: short trip time for a deviation from the outer limit value long trip time for a deviation from the inner limit value
^b)	cyl = grid periods (cycles); 1 cyl corresponds to 20 ms at 50 Hz or 16.66 ms at 60 Hz

Graphic illustrating the limits

IL	"Inner Limit" - inner limit value
OL	"Outer Limit" - outer limit value
(1)	Trip range

Freq. Inner Limit Max
Upper inner grid frequency limit value in Hz

Freq IL Max TripTime
Trip time ^A) for exceeding the upper inner grid frequency limit value in cyl ^B)

Freq. Inner Limit Min
Lower inner grid frequency limit value in Hz

Freq IL Min TripTime
Trip time ^A) for falling below the lower inner grid frequency limit value in cyl ^B)

Alt Freq Mode
For activating / deactivating alternative frequency limit values
ON / OFF

Alt Freq IL Max
Alternative upper inner grid frequency limit value in Hz

Alt Freq IL Max TT
Trip time ^A) for exceeding the alternative upper inner grid frequency limit value in cyl ^B)

Alt Freq IL Min
Lower alternative inner grid frequency limit value in Hz

Alt Freq IL Min TT
Trip time ^A) for falling below the alternative lower inner grid frequency limit value in cyl ^B)

Freq Outer Limit Max
Upper outer grid frequency limit value in Hz

Freq OL Max TripTime
Trip time ^A) for exceeding the upper outer grid frequency limit value in cyl ^B)

Freq Outer Limit Min
Lower outer grid frequency limit value in Hz

Freq OL Min TripTime
Trip time ^A) for falling below the lower outer grid frequency limit value in cyl ^B)

Redundant FAC Check
Can be switched on or off

Redundant UAC Check
Can be switched on or off

Freq Reconnect Max
Upper grid frequency limit value for reconnection to the public grid following disconnection due to impermissible parameter deviation
[Hz]

Freq Reconnect Min
Lower grid frequency limit value for reconnection to the public grid following disconnection due to impermissible parameter deviation
[Hz]

Freq Recon. IL Max
Upper inner grid frequency limit value for reconnection to the public grid following disconnection due to impermissible parameter deviation
[Hz]

Freq Recon. IL Min
Lower inner grid frequency limit value for reconnection to the public grid following disconnection due to impermissible parameter deviation
[Hz]

^A)	Different trip times can be assigned to the inner limit value IL and outer limit value OL. For example: short trip time for a deviation from the outer limit value long trip time for a deviation from the inner limit value
^b)	cyl = grid periods (cycles); 1 cyl corresponds to 20 ms at 50 Hz or 16.66 ms at 60 Hz

For setting the NL-MON (neutral conductor phase monitoring) switch-off values

Selection options

NL-MONitor On/Off / NL Uouter Limit Min / NL U OL Min TripTime / NL UMiddle Limit Min / NL U ML Min TripTime / NL Uinner Limit Min / NL U IL Min TripTime / NL Uinner Limit Max / NL U IL Max TripTime / NL UMiddle Limit Max / NL U ML Max TripTime / NL Uouter Limit Max / NL U OL Max TripTime

NL-MONitor On/Off	Selection options: ON / OFF / Stinger
NL Uouter Limit Min	Specification of the minimum external switch-off value
NL U OL Min TripTime	Specification of the operating time of the minimum external switch-off value
NL UMiddle Limit Min	Specification of the minimum middle switch-off value
NL U ML Min TripTime	Specification of the minimum middle switch-off value
NL Uinner Limit Min	Specification of the minimum internal switch-off value
NL U IL Min TripTime	Specification of the operating time of the minimum internal switch-off value
NL Uinner Limit Max	Specification of the maximum internal switch-off value
NL U IL Max TripTime	Specification of the operating time of the maximum internal switch-off value
NL UMiddle Limit Max	Specification of the maximum middle switch-off value
NL U ML Max TripTime	Specification of the operating time of the maximum middle switch-off value
NL Uouter Limit Max	Specification of the maximum external switch-off value
NL U OL Max TripTime	Specification of the operating time of the maximum external switch-off value

additional configurable switch off delay;
relates to all trip times and increases the trip times by the specified value
0 - 255 [cyl]

for setting special reactive power parameters

The parameters in this menu item enable the feed-in method of the inverter to be modified.

IMPORTANT! A detailed explanation of the settings can be found in the "Advanced Grid Features" section under: Reactive Power Mode.

Selection options

React. P. Mode / Const. Cosφ / Const. Cosφ TimeC. / Const. Q Rel. / Const. Q Rel. TimeC. / Const. Q Abs. / Const. Q Abs. TimeC. / Ch Cosφ (P) *-* / Ch Cosφ (P) TimeC. / Ch Cosφ (P) U-LockIn / Ch Cosφ (P) U-LockOut / Ch Cosφ (P) P-LockOut / Ch Q (U) *-* / Ch Q (U) Initial Delay / Ch Q (U) Offset Factor / Ch Q (U) TimeC. / Ch Q (U) P-LockIn / Ch Q (U) P-LockOut / Ch Q (U) Cosφ Min. / Ch Q (P) *-* / Ch Q (P) TimeC. / Ch Q (P) U-LockIn / Ch Q (P) U-LockOut / Ch Q (P) P-LockOut

-	0-0 / 0-1 / 1-0 / 1-1 / 2-0 / 2-1 / 3-0 / 3-1 respectively

React. P. Mode
for activating / deactivating reactive power mode

Selection options

Grid Power Priority / C. cosφ / C. Qrel / C. Qabs / cosφ/P / Q/U / Q/P / OFF

Grid Power Priority

For setting whether effective power (Active) or reactive power (Reactive) has priority

C. cosφ

Constant cos phi specification

C. Qrel

Constant specification of the relative reactive power in %

C. Qabs

Constant specification of absolute reactive power in VAr

cosφ/P

Cos phi specification depending on effective power

Q/U

Relative reactive power specification depending on current grid voltage

Q/P

Relative reactive power specification depending on effective power

OFF

Reactive power mode deactivated

first select one of the reactive power modes from the selection options
then set the parameters in the relevant reactive power mode

The reactive power modes:

Const. Cosφ

Constant cos phi specification

Once "Enter" has been pressed, the value for the cos φ power factor can be set:

-0.85 (ind.) - +0.85 (cap.) -- Galvo

-0.70 (ind.) - +0.70 (cap.) -- Symo S, Symo M 8k2,
Symo Hybrid, Primo 8k2, Primo US 8k2

-0.00 (ind.) - +0.00 (cap.) -- Symo M 20, Primo 15, Eco, Symo US 12, Symo US 24, Symo US (Eco)

Const. Cosφ TimeC.

Time constant at which a new set value of the power factor cos φ is activated

Const. Q Rel.

Constant specification of the relative reactive power in %

Once "Enter" has been pressed, the value for the reactive power relative to the nominal apparent power can be set.

Const. Q Rel. TimeC.

Time constant at which a new set value of the relative reactive power is activated

Const. Q Abs.

Constant specification of absolute reactive power in VAr

Once "Enter" has been pressed, the value for absolute reactive power can be set from 0 to the max. device output (inductive/capacitive) in VAr.

Const. Q Abs. TimeC.

Time constant at which a new set value of the absolute reactive power is activated

Ch Cosφ (P) *-*

Cosφ (P) characteristic:
Cos phi specification depending on effective power

Ch Cosφ (P) TimeC.

Time constant at which a new set value of the (respective) control is compensated for.
- Compensation after ~3x the time constant

Ch Cosφ (P) U-LockIn

Input of a voltage value; when this voltage value is exceeded the Cosφ (P) characteristic is activated.
80 - 120%

Ch Cosφ (P) U-LockOut

Input of a voltage value; when this voltage value is undershot the Cosφ (P) characteristic is deactivated.
80 - 120%

Ch Cosφ (P) P-LockOut

Input of a power value; when this power value is undershot the Cosφ (P) characteristic is deactivated.
0 - 100%

Ch Q (U) *-*

Q (U) characteristic:
Relative reactive power specification depending on current grid voltage

Ch Q (U) Initial Delay

Delays the application of the Q (U) control after the values Ch Q (U) 1 - x or 2 - x are undershot/exceeded
0 - 60 s

Ch Q (U) Offset Factor

Moves the Q (U) characteristic along the Q axis by a factor of -1 to +1

Ch Q (U) TimeC.

Time constant at which a new set value of the (respective) control is compensated for.
- Compensation after ~3x the time constant

Ch Q (U) P-LockIn

Input of a power value; when this power value is exceeded the Q (U) characteristic is activated.
0 - 100%

Ch Q (U) P-LockOut

Input of a power value; when this power value is undershot the Q (U) characteristic is deactivated.
0 - 100%

Ch Q (U) Cos. φ Min.

Input of a minimum cos phi value at which the inverter may feed in power.
0 - 1.0

Ch Q (P) *-*

Q (P) characteristic:
Relative reactive power specification depending on effective power

Ch Q (P) TimeC.

Time constant at which a new set value of the (respective) control is compensated for.
- Compensation after ~3x the time constant

Ch Q (P) U-LockIn

Input of a voltage value; when this voltage value is exceeded the Q (P) characteristic is activated.
80 - 120%

Ch Q (P) U-LockOut

Input of a voltage value; when this voltage value is undershot the Q (P) characteristic is deactivated.
80 - 120%

Ch Q (P) P-LockOut

Input of a power value; when this power value is undershot the Q (P) characteristic is deactivated.
0 - 100%

-	0-0 / 0-1 / 1-0 / 1-1 / 2-0 / 2-1 / 3-0 / 3-1 respectively 4 characteristic points 0 / 1 / 2 / 3 with the coordinates 0 (x) and 1 (y)

Frequency Dependent Power Reduction
(from grid frequency dependent power reduction)

When the GFDPR function is enabled and the specified grid frequency limit value is exceeded, the effective power is reduced according to a defined gradient.

IMPORTANT! A detailed explanation of the settings can be found in the "Advanced Grid Features" section under: GFDPR - Grid frequency-dependent power reduction P(f).

Selection options

GFDPR On/Off / P-Reduct. Reference /P-Increa. Reference / Enable Limit / Enable Limit Under F. / Intentional Delay / Derating Gradient / Derating Gradient U.F. / Stop Frequency / Stop Frequency U.F. / Change Time Constant / Frequency Test Time / Disable Limit Min. / Disable Limit Max. / Alt. Ret. Grad Thr. / Return Gradient 1 / alt. Return Grad. 1 / Use Return Grad. 2 / Return Gradient 2 / P(f) f transition Of**** / P(f) f transition Uf****

GFDPR On/Off Activation or deactivation of function
Selection options	Off / On DisHyst / On
Off	Function deactivated
On DisHyst	Function activated, no hysteresis
On	Function activated, with hysteresis
P-Reduct. Reference Indicates the reference power for calculating the power reduction in the event of over frequency.
Selection options	Pn-Pnkx / Pm-Pnkx / Pm-Pmkx / act. Pwr. / nom. Pwr.
Pm	Actual capacity during entry
Pn	Nominal output of the device
k	Derating Gradient
x	Current frequency
act. Pwr.	Actual power at the time of entering into over frequency
nom. Pwr.	Nominal device output
P-Increa. Reference Indicates the reference power for calculating the power reduction in the event of under frequency.
Selection options	Pn-Pnkx / Pm-Pnkx / Pm-Pmkx
Pm	Actual capacity during entry
Pn	Nominal output of the device
k	Derating Gradient
x	Current frequency
Enable Limit for setting the frequency limit value above which a power reduction takes place
Enable Limit Under F. (only on hybrid inverters) for setting the frequency limit value above which a power increase takes place
Intentional Delay Delays the application of the P (f) control after the Enable Limit is exceeded 0 - 60 s
Derating Gradient for setting the gradient at which the effective power is reduced 0.01 - 100%/Hz
Reference variable	current power at the start of power reduction
Derating Gradient U.F. (only on hybrid inverters) for setting the gradient at which the effective power is increased 0.01 - 100%/Hz
Reference variable	current power at the start of power increase
Stop Frequency for setting the frequency limit value up to which a power reduction takes place.
Stop Frequency U.F. (only on hybrid inverters) for setting the frequency limit value up to which a power increase takes place
Change Time Constant Time constant at which a new set value of the (respective) control is compensated for. - Compensation after ~3x the time constant 0 - 60 s
Frequency Test Time for setting the waiting time after which the inverter will increase the power again (once the power has reduced such that the grid frequency is within the permitted frequency range between Disable Limit Max. and Disable Limit Min.). 0 - 600 s
Disable Limit Min. / Disable Limit Max. for setting the upper / lower frequency range limit value
Alt. Ret. Grad Thr. for setting the threshold above which the "Return Gradient 1" or the "alt. Return Grad. 1" is applied. e.g.: If the difference between the rated power and the current reduced power is less than or equal to the threshold, "Return Gradient 1" is applied. If the difference between the rated power and the current reduced power is greater than the threshold, "alt. Return Grad. 1" is applied. 0.01 - 100% 100% means that "Return Gradient 1" is always applied.
Return Gradient 1 for setting the rate of change at which the inverter increases the effective power from the current reduced value to the original value. 0.01 - 100%/s
Reference variable	Device rated power
alt. Return Grad. 1 for setting the rate of change at which the inverter increases the effective power from the current reduced value to the original value; is activated if the difference between the rated power and the current reduced power is greater than the "Alt. Ret. Grad Thr.". 0.01 - 100%/s
Reference variable	Difference between the output at the start of power reduction and the current output
Use Return Grad. 2 for activating/deactivating the rate of change at which the inverter increases the effective power from the original value to the device rated power.
Selection options	OFF / ON
OFF	raising the effective power from the original value to the device rated power takes place according to "Return Gradient 1"
ON	raising the effective power from the original value to the device rated power takes place according to "Return Gradient 2"
Return Gradient 2 for setting the rate of change at which the inverter increases the effective power from the original value to the device rated power. 0.01 - 100%/s
Reference variable	Device rated power
P(f) f transition Of**** Frequency at which the device reaches an output power of 0 W with active battery. If the grid frequency continues to rise, energy is drawn from the public 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.
P(f) f transition Uf**** Frequency at which the device reaches an output power of 0 W with active battery (charging power is reduced). If the grid frequency continues to drop, additional energy is fed into the grid. This energy can come from the module array or from the battery. If there is no battery in the system or it is not active, this parameter has no function.

Voltage Dependent Power Reduction
(from grid voltage dependent power reduction)

When the GVDPR function is activated and the specified grid voltage limit value is exceeded, the maximum effective power is reduced.
The power is reduced by a specified gradient according to the phase with the highest voltage.

IMPORTANT! A detailed explanation of the settings can be found in the "Advanced Grid Features" section under: GVDPR - Grid voltage-dependent power reduction P(U).

Selection options

GVDPR On/Off / P-Reduct. Reference / Enable Limit / Derating Gradient / Enable Limit UnderV. / Derating Gradient UnderV. / Change Time Constant / Event Message / P(U) Stop Voltage OV*** / P(U) Stop Power OV**** / P(U) Stop Voltage UV*** / P(U) Stop Power UV****

GVDPR On/Off Activates or deactivates the function
Selection options	Off / On
Off	Function deactivated
On	Function activated
P-Reduct. Reference Indicates the reference power for calculating the power reduction in the event of a surge.
Selection options	Pn-Pnkx / Pm-Pnkx / Pm-Pmkx / act. Pwr. / nom. Pwr.
Pm	Actual capacity during entry
Pn	Nominal output of the device
k	Derating Gradient
x	Current frequency
act. Pwr.	Actual power when entering into the surge range
nom. Pwr.	Nominal device output
Enable Limit for setting the grid voltage limit value above which a power reduction takes place 208 - 300 V
Derating Gradient for setting the gradient at which the effective power is reduced 0.01 - 100%/V
Enable Limit UnderV. for setting the grid voltage limit value above which a power increase takes place 200 - 250 V
Derating Gr. UnderV. for setting the gradient at which the effective power is increased 0.01 - 100%/V
Change Time Constant for setting a time constant by which the inverter approaches the limitation target 0.01 - 600 s
Event Message for activating / deactivating event messages
Selection options	OFF / ON
P(U) Stop Voltage OV**** Grid voltage limit value up to which the power reduction takes place. The gradient is calculated automatically from the parameters Activation Threshold Overvoltage and Power at Stop Voltage at Overvoltage. The parameters Gradient Overvoltage and Calculation Mode have no function. 0 -311 V (default: 270 V)
P(U) Stop Power OV*** Reference power when the set grid voltage limit value is reached. 0 - 100% (default: 0%)
P(U) Stop Voltage UV**** Grid voltage limit value up to which the charging power of the battery is reduced. The gradient is calculated automatically from the parameters Activation Threshold Undervoltage and Power at Stop Voltage at Undervoltage. The parameters Gradient Undervoltage and Calculation Mode have no function. 0 -311 V (default: 270 V)
P(U) Stop Power UV*** Reference power when the set grid voltage limit value is reached. Only for devices with battery in charging mode. 0 - 100% (default: 0%)

for manual specification of a max. output power value

Setting range

150 - max. W (kW)
dependent on the inverter size

Activation and deactivation of the Softstart function, setting the gradient for the startup ramp

Selection options

Softstart On/Off / Softstart Gradient

Softstart On/Off for activating and deactivating the Softstart function
Off	Function deactivated
On acFlt	Function activated; The Softstart Gradient is only applied in the event of a prior AC error.
On	Function activated; The Softstart Gradient is applied whenever start up is energised.
Softstart Gradient for setting the gradient for the startup ramp 0.01 - 100 %/s

„Voltage Fault Ride Through“
Function for handling grid faults (grid voltage drops) as part of dynamic grid backup. Three independent voltage ranges can be set with different behaviours.

IMPORTANT! A detailed explanation of the settings can be found in the "Advanced Grid Features" section under: LVFRT - Dynamic grid backup during temporary drops in grid voltage.

VRT Mode	VRT Mode universally switches on or off
R1/2/3 Calculation Mode	Off: Behaviour is equivalent to Passive Mode. Passive: During the grid fault the inverter behaves passively, i.e. the same alternating current as before the grid fault is fed into the grid. Zero Current: During the grid fault the alternating current is adjusted/reduced to zero. The inverter is not disconnected from the grid. Active Nominal Based: during the grid fault a pure symmetrical reactive current (positive-sequence system) is fed into the grid for dynamic grid backup. The active current is adjusted to zero. Calculation according to the formula. Active Boundary Based: Currently not supported Active Unbalanced Compensation Current (Act. UBCC): During the grid fault any asymmetrical reactive current (positive-sequence system and negative-sequence system) is fed into the grid for optimum phased grid backup. If technically possible, an additional active current is fed into the grid. Calculation according to the formula.
R1/2/3 Detection Mode (only up to firmware version fro33430.upd)	Mode like an FRT is identified Static: The calculated voltage RMS values are used for grid fault detection. A grid fault is identified when one or more grid voltage RMS values exceed or fall below the set static limit. Dynamic: is currently not supported PosNorm: The positive-sequence system and negative-sequence system voltages are used for grid fault detection. A grid fault is identified when the combination of positive-sequence system and negative-sequence system voltage exceeds or falls below the set static limit. Dynamic: Currently not supported
R1/2/3 Detection Mode (Standard 50549)	Determines which voltage system is used to detect a grid fault (voltage drop or voltage surge) 0 = L-N Voltage 1 = L-L Voltage 2 = L-L and L-N Voltage
R1/2/3 Static Threshold	Static boundary to identify a LVRT or HVRT. Specification in % derived from nominal voltage. 0 - 200%
R1/2/3 Dynamic Limit (only up to firmware version fro33430.upd)	Dynamic boundary to identify a LVRT or HVRT. Calculated based on the 1min floating average value of the grid voltage. Specification in % derived from nominal voltage. 0 - 200%
R1/2/3 k-Factor positive-sequence system	Multiplication factor for calculating the compensation reactive current (positive-sequence system) during the grid fault. Only effective when Mode Active Nominal Based or Active UnbalancedCompensationCurrent (Act. UBCC) is set.
R1/2/3 k-Factor negative-sequence system	Multiplication factor for calculating the compensation reactive current (negative-sequence system) during the grid fault. Only effective when CalculationMode Active UnbalancedCompensationCurrent (Act. UBCC) is set.
FRT Limit Compensation Current overexcited	Relative limit of the dynamic additional reactive current during Voltage Ride Through for overexcited operation.
FRT Limit Compensation Current underexcited	Relative limit of the dynamic additional reactive current during Voltage Ride Through for underexcited operation.
FRT Sudden Voltage Change Mode	Activates / deactivates the detection of sudden voltage changes.
FRT Sudden Voltage Change Insensitivity Range	Percentage value that a sudden voltage jump must exceed or fall below in order to activate FRT mode.
FRT Sudden Voltage Change Deactivation Time	Timeout after detecting a sudden voltage jump, after which the inverter no longer runs in FRT mode and switches back to normal operation.

DC-I. InnerLimit Mode
deactivates/activates the lower set limit values for DC Injection

Selection options:

OFF / ABSOLUTE / RELATIVE

DC-I I.L. Absolute:	Inner absolute DC Injection limit value 0 - 10 A
DC-I I.L. Relative:	Inner relative DC Injection limit value based on the device nominal current 0 - 10 %
DC-I I.L. TripTime:	Trip time in seconds for violation events when the inner absolute and relative limit value is exceeded 0 - 10 s

DC-I. OuterLimit Mode
deactivates/activates the lower set limit values for DC Injection

Selection options:

OFF / ABSOLUTE / RELATIVE

DC-I O.L. Absolute:	Outer absolute DC Injection limit value 0 - 10 A
DC-I O.L. Relative:	Outer relative DC Injection limit value based on the device nominal current 0 - 10 %
DC-I O.L. TripTime:	Trip time in seconds for violation events when the outer absolute and relative limit value is exceeded 0 - 10 s

In some cases, the inverter may have an unpermissable influence (attenuation, amplification) on ripple control signals. Ripple Control can counteract this behaviour.

Selection options:

Mode / Signal Frequency / Grid Inductance

Mode:

On / Off

Signal Frequency:

Frequency with which the ripple control signal is sent

Grid Inductance:

Inductance of the connection point

Selection options:

Mode / Udc Link Voltage

Mode:

Using Mode the intermediate circuit voltage can be increased to reduce unavoidable leakage currents in the event of high module capacities to ground

Udc Link Voltage:

The intermediate circuit voltage increase is configured to a default value and can be adjusted when necessary using this value

This function activates the stand-alone power system detection. If an undesirable stand-alone operation state is detected, the inverter is shut down.

Selection options	OFF / Sym_Asym / Sym

OFF:	no active stand-alone operation detection
Sym_Asym:	all types of stand-alone operation are detected; on three-phase devices also stand-alone operation on any individual phase.
Sym:	only symmetrical stand-alone operation states are detected; on three-phase devices only stand-alone operation on all three phases at the same time.

On single-phase devices, there is no difference between the settings Sym_Asym and Sym.

The preset value corresponds to the quality of the oscillating test circuit required by the relevant standard. The lower the value, the fewer disturbances to the grid. The higher the value, the greater the influence on the grid.

Setting range

0 - 10

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 limit and last longer than the set trip time, the inverter is shut down. ROCOF detection can be used as a passive stand-alone operation detection method.

Selection options

ROCOF On/off / ROCOF Limit / ROCOF TripTime

ROCOF On/off	for activating and deactivating the ROCOF functionality. When the ROCOF functionality is deactivated, a change in frequency does not cause a switch-off event. Default setting: Off
ROCOF TripTime	Operating time within which the device switches off in case of a too rapid change in frequency 50 - 16,000 ms (default: 300 ms)
ROCOF Limit	Limit value for change in frequency that triggers a switch-off if ROCOF is activated. 50 - 99,999 mHz/s (default: 2500 mHz/s)

The ramp rates limit the maximum rate of change of the effective power that is triggered by external inputs (e.g. Modbus, DRM, PSC editor). If slower ramp rates are defined by the characteristic mode (e.g. P(U), P(F) or start-up), the lowest rate of change is used.
The value 0 corresponds to the maximum rate of change.

When starting up the system, the Datamanager and inverter control (ReCerbo PC board) should be synchronised so that both control components are fully ready for use. This allows many problems caused by different system statuses to be avoided.
The ReCerbo blocks feed-in enabling until the Datamanager has fully booted up and all system-relevant services have started.
For devices without a Datamanager, the setting must be Off, otherwise the device will not start. When using the dynamic feed-in limitation, the "Permanent" setting can be used to prevent unauthorised feed-in during the start-up phase or in the event of a Datamanager fault.

Requirements:
Datamanager version: 3.7.3-2
ReCerbo version: 0.3.11.10

Selection options

DM FailSafe Mode / DM FailSafe Behaviour

DM FailSafe Mode	Off / Permanent
DM FailSafe Behaviour	Disconn.

Initial Start Time Grid monitoring time before the inverter is started up in s 1 - 900 s
Reconnect Time Grid monitoring time before the inverter is started up after a grid fault in s 1 - 900 s

For switching on / off the Powerline Communication (PLC) signal (Keep Alive Signal) according to the SunSpec standard "Communication Signal for Rapid Shutdown".

Selection options:	Powerline COM Mode
Powerline COM Mode	SunSpec / Off

These parameters can be used to set the behaviour of the Arc Fault Circuit Interrupter at the DC terminals of the inverter. The DC Arc Fault Protection function protects against arcing faults and contact faults. Faults that occur in the current and voltage curve are continuously evaluated and the circuit is switched off when a contact fault is detected. This prevents overheating on faulty contacts and possible fires.

Parameter	Range of values	Description
"Arc Fault Protection Equipment (AFPE)"		For activating and deactivating the Arc Fault Circuit Interrupter. The parameter "Automatic reconnects" is only considered when the "Arc Fault Detection (AFD)" is activated.
	Off	Arcs are not detected.
	On	The Arc Fault Circuit Interrupter is active.
"Automatic Reconnects"		If more arcs have been detected within 24 hours than are defined in "Automatic Reconnects", the inverter will not make any further attempt to start feeding energy into the grid.
	-1	The 24-hour counter is deactivated. The inverter restarts feeding energy into the grid 5 minutes after each arc detected.
	0 - No Reconnection	After an arc has been detected, no further attempt is made to start feeding energy into the grid and status code 240 is displayed.
	1 ‑ 4	After a shutdown due to an arc, 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 status code 240 is displayed.

The country setup entered on the inverter ensures that the relevant operating modes and settings for local standards and guidelines are specified.
However, in some situations it may be worthwhile to adapt the preset country-specific operating modes and settings to the local grid situation.

This will help to ensure more reliable operation of the inverter in the grid, while enabling the inverter to actively support the public grid. For this purpose, the grid voltage and grid frequency must be within defined limits.
The voltage and frequency stability can be actively influenced via the inverter by monitoring the feeding of effective power and reactive power into the grid.

Simply decreasing the effective power in order to reduce high grid voltage levels can reduce the energy generated by the photovoltaic system.
One alternative is to switch the reactive power between the inverter and the grid. Even though the reactive power is not consumed or converted into effective power and simply oscillates between the inverter and the grid, the current fed in will increase.

Regardless of the active 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 grid. The grid voltage rises.
In under-excited mode or inductive mode, reactive power is taken from the inverter. The grid voltage falls.

Capacitive mode is shown on the inverter display by a positive sign +.
Inductive mode is shown on the inverter display by a negative sign -.

The country setup entered on the inverter ensures that the relevant operating modes and settings for local standards and guidelines are specified.
However, in some situations it may be worthwhile to adapt the preset country-specific operating modes and settings to the local grid situation.

This will help to ensure more reliable operation of the inverter in the grid, while enabling the inverter to actively support the public grid. For this purpose, the grid voltage and grid frequency must be within defined limits.
The voltage and frequency stability can be actively influenced via the inverter by monitoring the feeding of effective power and reactive power into the grid.

Simply decreasing the effective power in order to reduce high grid voltage levels can reduce the energy generated by the photovoltaic system.
One alternative is to switch the reactive power between the inverter and the grid. Even though the reactive power is not consumed or converted into effective power and simply oscillates between the inverter and the grid, the current fed in will increase.

Regardless of the active 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 grid. The grid voltage rises.
In under-excited mode or inductive mode, reactive power is taken from the inverter. The grid voltage falls.

Capacitive mode is shown on the inverter display by a positive sign +.
Inductive mode is shown on the inverter display by a negative sign -.

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

cos phi = 0.85, Q_rel = 53 % ^(Galvo)
cos phi = 0.70, Q_rel = 71 % ^{(Symo S, Symo M -8k2, Symo Hybrid, Primo -8k2, Primo US -8k2)}
cos phi = 0.00, Q_rel = 100 % ^{(Symo M -20, Primo US -15, Eco, Symo US -24, Symo US (Eco)}

The figure below shows the potential operating range of the inverter. All valid operating points defined by effective power P and reactive power Q are within the grey area.

under-excited (inductive)		over-excited (capacitive)

Q = Reactive power [VAr] P = Effective power [W] S_n = Nominal apparent power [VA] cos phi = power Pactor Q_rel = Operative reactive power limit of the inverter [%]

Example for Fronius Galvo

For example, fixed values or curves can be specified within the operating range that define the reactive power response of the inverter. Reactive power operation is only possible when a DC supply is present.

The following options for switching reactive power and for controlling the inverter are available:

Const. Cos φ
Const. Q Rel
Const. Q Abs
Ch Cos φ(P)
Ch Q (U)
Ch Q (P)

Only one reactive power mode can be used at any one time to control the inverter.

Constant specification of power factor cos φ

Setting range:

-0.85 - +0.85 ^(Galvo)
-0.70 - +0.70 ^{(Symo S, Symo M -8k2, Symo Hybrid, Primo -8k2, Primo US -8k2)}
-0.00 - +0.00 (Symo M -20, Primo US -15, Eco, Symo US -24, Symo US (Eco)

Example:
cos φ = -0.9

under-excited (inductive)		over-excited (capacitive)

Q = Reactive power [VAr] P = Effective power [W] Sn = Nominal apparent power [VA] cos φ = Power factor Q_rel = Operative reactive power limit of the inverter [%]

Example for Fronius Galvo

Constant specification for relative reactive power in % in relation to the nominal apparent power of the inverter

Setting range:

-53 - 0 - +53 ^(Galvo)
-71 - 0 - +71 ^{(Symo S, Symo M -8k2, Symo Hybrid, Primo -8k2, Primo US -8k2)}
-100 - 0 - +100 ^{(Symo M -20, Primo US -15, Eco, Symo US -24, Symo US (Eco)}

Example:
Q_rel = -32 %

under-excited (inductive)		over-excited (capacitive)

Q = Reactive power [VAr] P = Effective power [W] S_n = Projected apparent power [VA] cos φ = Power factor Q_rel = Operative reactive power limit of the inverter [%]

Example for Fronius Galvo

Constant specification of absolute reactive power in VAr

Setting range: -n - 0 - +n [VAr]

n = maximum reactive power that can be set depending on the respective inverter

Example:
Q_rel = -n₁ VAr

under-excited (inductive)		over-excited (capacitive)

Q = Reactive power [VAr] P = Effective power [W] S_n = Nominal apparent power [VA] cos φ = Power factor Q_rel = Operative reactive power limit of the inverter [%]

Example for Fronius Galvo

Specification of the power factor cos φ depending on effective power P

The characteristic is defined by max. 4 characteristic points 0 - 1 - 2 - 3.
The coordinates must be entered for the characteristic points on the 0 (x) axis and on the 1 (y) axis.

-0,85 - 1 - +0,85 ^a
-0,70 - 1 - +0,70 ^b,c,e,f,l
-0,00 - 1 - +0,00 ^d,g,h,i,j,k

Characteristic point	Coordinates	Setting range
0	0-0 (x)	P: 0 - 100 %
	0-1 (y)	cos φ (see table)
1	1-0 (x)	P: 0 - 100 %
	1-1 (y)	cos φ (see table)
2	2-0 (x)	P: 0 - 100 %
	2-1 (y)	cos φ (see table)
3	3-0 (x)	P: 0 - 100 %
	3-1 (y)	cos φ (see table)

		Axis
		Characteristic point

Example:
Curve defined by 4 characteristic points
0: P = 15 %, cos φ = +0.85
1: P = 25 %, cos φ = 1
2: P = 45 %, cos φ = 1
3: P = 90 %, cos φ = -0.90

Example for Fronius Galvo

*	Apparent power limit

Specification of relative reactive power depending on grid voltage

The characteristic is defined by max. four characteristic points 0 - 1 - 2 - 3.
The coordinates must be entered for the characteristic points on the 0 (x) axis and on the 1 (y) axis.

-53 - 0 - +53 ^a
-71 - 0 - +71 ^b,c,e,f,l
-100 - 0 - +100 ^d,g,h,i,j,k

Characteristic point	Coordinates	Setting range
0	0-0 (x)	U: 80 -120%
	0-1 (y)	Q (see table)
1	1-0 (x)	U: 80 -120%
	1-1 (y)	Q (see table)
2	2-0 (x)	U: 80 -120%
	2-1 (y)	Q (see table)
3	3-0 (x)	U: 80 -120%
	3-1 (y)	Q (see table)

		Axis
		Characteristic point

Example for Fronius Galvo

Example:
Characteristic defined by four characteristic points
0: U = 95%, Q = 32%
1: U = 97% Q = 0%
2: U = 104%, Q = 0%
3: U = 105%, Q = -32%

(1)	Ch Q (U) P-Lockout = 5%
(2)	Ch Q (U) P-Lockin = 30%
(3)	Ch Q (U) Cos. φ Min. = 0.9

* Detail:

Specification of relative reactive power depending on effective power

The characteristic is defined by max. 4 characteristic points 0 - 1 - 2 - 3.
The coordinates must be entered for the characteristic points on the 0 (x) axis and on the 1 (y) axis.

-53 - 0 - +53 ^a
-71 - 0 - +71 ^b,c,e,f,l
-100 - 0 - +100 ^d,g,h,i,j,k

Characteristic point	Coordinates	Setting range
0	0-0 (x)	P: 0 -100 %
	0-1 (y)	Q (see table)
1	1-0 (x)	P: 0 -100 %
	1-1 (y)	Q (see table)
2	2-0 (x)	P: 0 -100 %
	2-1 (y)	Q (see table)
3	3-0 (x)	P: 0 -100 %
	3-1 (y)	Q (see table)

		Axis
		Characteristic point

Example:
Characteristic defined by 4 characteristic points
0: P = 0 %, Q = 0 %
1: P = 25 %, Q = 0 %
2: P = 50 %, Q = 0 %
3: P = 95 %, Q = -32 %

Example for Fronius Galvo

The characteristic operating mode for switching reactive power can also be enabled or disabled using the Lock-In / Lock-Out parameters.

If a defined starting threshold is exceeded (Lock-In), the characteristic operating mode is enabled and the inverter feeds in reactive power according to the relevant characteristic.
If a defined starting threshold is undershot (Lock-Out), the characteristic operating mode is disabled regardless of whether another parameter has exceeded or is about to exceed the Lock-In threshold. Lock-Out takes priority over Lock-In.
When the characteristic operating mode is disabled, reactive power is no longer fed into the grid.

GFDPR = Grid Frequency Dependent Power Reduction

When the GFDPR function is enabled and the defined grid frequency limit value is exceeded, the effective power is reduced according to a defined gradient.
Once the grid frequency falls within the permitted frequency range again following successful power reduction, return to full power takes place depending on the country setup as follows:

GFDPR ON DisHyst mode
The inverter increases the power from the current reduced value to the original value in accordance with the same gradient used for power reduction.
GFDPR ON mode
The inverter will not increase the power to the original value until the frequency is in the command value range for a specific length of time.

GFDPR = Grid Frequency Dependent Power Reduction

When the GFDPR function is enabled and the defined grid frequency limit value is exceeded, the effective power is reduced according to a defined gradient.
Once the grid frequency falls within the permitted frequency range again following successful power reduction, return to full power takes place depending on the country setup as follows:

GFDPR ON DisHyst mode
The inverter increases the power from the current reduced value to the original value in accordance with the same gradient used for power reduction.
GFDPR ON mode
The inverter will not increase the power to the original value until the frequency is in the command value range for a specific length of time.

GFDPR ON/OFF = On DisHyst

with Derating Gradient

(1)	Enable Limit = 50.3 Hz
(2)	Derating Gradient = 84 %/Hz
(3)	Enable Limit UnderF.[Hz]
(4)	Derating Gradient U.F. [%/Hz]

P_nom	Nominal output
P_m	Actual power at the moment the limit value is exceeded
P_red	Reduced power

with Stop Frequency

(1)	Enable Limit = 50.3 Hz
(2)	Stop Frequency = 50.5 Hz
(3)	Enable Limit UnderF. = 49.8 Hz
(4)	Stop Frequency U.F. = 49.7 Hz

P_nom	Nominal output
P_m	Actual power at the moment the limit value is exceeded
P_red	Reduced power

GFDPR ON/OFF = On

(1)	Enable Limit = 50.3 Hz
(2)	Derating Gradient = 84 %/Hz
(3)	Frequency Test Time = 30 s
(4)	Disable Limit Max. = 50.1 Hz
(5)	Disable Limit Min. = 49.8 Hz

P_nom	Nominal output
P_m	Actual power at the moment the limit value is exceeded
P_red	Reduced power

Example:
Alt. Ret. Grad Thr. = 25 %

P_nom	Nominal output
P_m	Actual power at the moment the limit value is exceeded
P_red	Reduced power

(1)	Derating Gradient
(2)	Frequency Test Time
(3)	Return Gradient 1
(4)	alt. Return Grad. 1
(5)	Alt. Ret. Grad Thr. P_m - P_red </= 25 %
(6)	Alt. Ret. Grad Thr. P_m - P_red > 25 %
(7)	Initial Delay

At P_red the grid frequency returns to the permissible range.
After the end of the delay time (2) specified by the standard, the power is increased by one of the following gradients to the output value P_m:

Curve 1 - black

The difference between the current power P_m and the reduced power P_red is less than or equal to the value entered for "Alt. Ret. Grad Thr." of 25 % (5).
This increases the power by the nominal output related gradient "Return Gradient 1" (3) to the output value P_m.

Curve 2 - grey

The difference between the current power P_m and the reduced power P_red is greater than the value entered for "Alt. Ret. Grad Thr." of 25 % (5).
This increases the power by the alternative difference power related gradient "alt. Return Grad. 1" (4) to the output value P_m.

P_nom	Nominal output
P_m	Actual power
P_red	Reduced power

(1)	Derating Gradient
(2)	Frequency Test Time
(3)	Return Gradient 1
(4)	Return Gradient 2
(5)	Initial Delay

Settings:
Use Return Grad. 2 = 1
Return Gradient 2 = n %/s

n ... value

At P_red the grid frequency returns to the permissible range.
After the end of the delay time (2) specified by the standard, the power is increased by a nominal output related gradient (3) to the output value P_m.
The power is then increased by one of the other nominal output related gradients (4) to the device nominal output P_nom.

GVDPR = Gradual Voltage Dependent Power Reduction
(power reduction dependent on the grid voltage)

To largely prevent the inverter being switched off when the grid voltage is too high due to the requirements of various standards and directives, the GVDPR function can be used to slightly reduce the power of feeding in, in accordance with the highest phase voltage.
This makes the yield losses less than they would be if the inverter was completely switched off.

(1)	Enable Limit [V]
(2)	Derating Gradient [%/V]
(3)	Enable Limit UnderV. [V]
(4)	Derating Gradient UnderV. [%/V]

P_nom	Nominal output
P_m	Actual power at the moment the limit value is exceeded
U_nom	Nominal voltage

Power waveshape depending on grid voltage

GVDPR = Gradual Voltage Dependent Power Reduction
(power reduction dependent on the grid voltage)

To largely prevent the inverter being switched off when the grid voltage is too high due to the requirements of various standards and directives, the GVDPR function can be used to slightly reduce the power of feeding in, in accordance with the highest phase voltage.
This makes the yield losses less than they would be if the inverter was completely switched off.

(1)	Enable Limit [V]
(2)	Derating Gradient [%/V]
(3)	Enable Limit UnderV. [V]
(4)	Derating Gradient UnderV. [%/V]

P_nom	Nominal output
P_m	Actual power at the moment the limit value is exceeded
U_nom	Nominal voltage

Power waveshape depending on grid voltage

VFRT = Voltage Fault Ride Through
Function for dynamic grid backup during grid faults (voltage drops or rises) in the grid in order to prevent an undesirable shutdown of the feed-in power and the collapse of the system. There are a range of selection options for the function (type of error detection, adjusting the fault limits, optional feeding in of additional compensation reactive currents, etc.).

Inverters with the VFRT function activated are not disconnected from the grid during grid faults (the duration of such grid faults can, depending on the grid voltage change, last between a few 100 milliseconds and a few minutes) and can therefore immediately feed the full power into the grid when the fault is resolved, without having to wait for the restart time.
If required by the electricity retailer (or by a country-specific standard), by adjusting the VFRT function accordingly, the inverter can feed an additional compensation reactive current into the grid during the grid fault for targeted grid backup.

The following variants can also be set:

Zero Current: during the grid fault the fed-in alternating current is adjusted to zero.
Passive: during the grid fault the alternating current is adjusted to the value before the fault (pre-fault current).

Example of a possible VFRT specification:
Voltage drop up to 0% Uc lasting up to 150 ms
(2) = Time at which failure occurs
Uc = Nominal voltage
U = voltage measured at the terminals of the inverter

Example of VFRT - Voltage waveshape limiting curves

If the voltage is above the limit line (1), the inverter must not switch off.
Any feeding in of an additional compensation current during the grid fault must be agreed with the grid operator.
If the measured voltage is below the limit line (1), the inverter can be disconnected from the grid. The inverter is safely disconnected from the grid according to the set operating times for the inner and outer voltage limit values.

When the VFRT function is disabled, the inverter does not feed in any dynamic reactive current if the voltage drops rapidly.

VFRT = Voltage Fault Ride Through
Function for dynamic grid backup during grid faults (voltage drops or rises) in the grid in order to prevent an undesirable shutdown of the feed-in power and the collapse of the system. There are a range of selection options for the function (type of error detection, adjusting the fault limits, optional feeding in of additional compensation reactive currents, etc.).

Inverters with the VFRT function activated are not disconnected from the grid during grid faults (the duration of such grid faults can, depending on the grid voltage change, last between a few 100 milliseconds and a few minutes) and can therefore immediately feed the full power into the grid when the fault is resolved, without having to wait for the restart time.
If required by the electricity retailer (or by a country-specific standard), by adjusting the VFRT function accordingly, the inverter can feed an additional compensation reactive current into the grid during the grid fault for targeted grid backup.

The following variants can also be set:

Zero Current: during the grid fault the fed-in alternating current is adjusted to zero.
Passive: during the grid fault the alternating current is adjusted to the value before the fault (pre-fault current).

Example of a possible VFRT specification:
Voltage drop up to 0% Uc lasting up to 150 ms
(2) = Time at which failure occurs
Uc = Nominal voltage
U = voltage measured at the terminals of the inverter

Example of VFRT - Voltage waveshape limiting curves

If the voltage is above the limit line (1), the inverter must not switch off.
Any feeding in of an additional compensation current during the grid fault must be agreed with the grid operator.
If the measured voltage is below the limit line (1), the inverter can be disconnected from the grid. The inverter is safely disconnected from the grid according to the set operating times for the inner and outer voltage limit values.

When the VFRT function is disabled, the inverter does not feed in any dynamic reactive current if the voltage drops rapidly.

A number of countries differentiate between different grid fault regions, such as the USA and Germany. This means, depending on the extent of the voltage change, a different alternating current calculation method must be used.

This can be achieved by setting what are known as the VFRT regions accordingly. Three individual regions can be configured. A detection limit, a fault detection mode and a current calculation mode can be selected for each region.

The detection limit for a region is a relative voltage level and is specified in percent derived from the AC nominal voltage. Values greater than 100% are handled as HVRT (High Voltage Ride Through), values lower than 100% are handled as LVRT (Low Voltage Ride Through).

The following settings can be made for each region

FRT-Mode (0=off, 1=passive, 2 = zero current, 3 = active nominal based, 4 = active boundary based, 5 = Active Unbalanced Compensation Current)
Detection Mode (0 = static, 1 = dynamic, 2 = Uac Pos Norm)
Static Limit (voltage in % derived from nominal voltage)
Dynamic Limit (voltage in % derived from the nominal voltage)
k factor positive sequence for active mode
k factor negative sequence for active mode

If the measured grid voltage is within one of the marked areas (regions), the respective current calculation mode is activated.

The graph describes the characteristic of how an additional compensation reactive current is fed into the grid depending on the measured grid voltage.

The upper voltage limit at +10% is the detection limit for VFRT-Region1 (HVRT), the lower voltage limit at -10% is the detection limit for VFRT-Region2 (LVRT1).

Between these two limits (normal voltage range) no grid fault is detected and therefore no additional compensation reactive current is fed into the grid. If the measured grid voltage is below or above the normal voltage range, a compensation reactive current depending on the K-Factor is fed into the grid.

If there is a voltage drop (LVRT), the inverter is overexcited and as a result supports the grid voltage. In the event of overvoltage (HVRT), the inverter is underexcited and as a result counters a voltage rise.

The graph and reactive current characteristic apply to compensation reactive currents in the positive-sequence system and negative-sequence system.

The K-Factor and the upper and lower voltage limits define the voltage level at which feeding in of reactive current is activated and also how high this current value should be.
When the K-Factor = 0, the inverter does not feed any additional reactive current into the grid in the event of a voltage drop.

The K-Factor can be determined from the following graph:

The following calculation rules apply both to positive-sequence system and negative-sequence system compensation reactive currents:

Un	Nominal voltage of the inverter
U₀	Voltage measured at the inverter before the grid fault (pre-fault voltage)
U	Voltage measured at the inverter
I_n	Nominal current of the inverter
I_B0	Fed-in reactive current before the grid fault
I_B	Resulting total reactive current during the grid fault
Δ I_B	Additional fed-in compensation reactive current during the grid fault

Δ U = U - U₀ ; Δ I_B = I_B - I₀

(1)	DeadBand Low
(2)	DeadBand High
(3)	Required additional reactive current
(4)	Voltage drop or voltage rise

Reactive current droop:

k =

Δ I_B / I_n

Δ U / U_n

Typical example of set values from the graph:
U_max = 110%
U_min = 90%
k = 2.0

Service Menü - SnapINverter Service Manual

General

General

General

Safety

CAUTION!

Firmware version

Opening a Service menu

Opening a Service menu

Opening a Service menu

Setting menu entries, general

Service Basic menu

Access code for the Service Basic menu

Access code for the Service Basic menu

Overview of menu items in the Service Basic menu

MPP Tracker 1

MPP Tracker 2

USB Eventlog

Input signal

SMS / relay

Grounding setting (only Fronius Galvo)

Insulation Settings

TOTAL reset

NOTE!

Service Error Counter menu

Access code for the Service Error Counter menu

Access code for the Service Error Counter menu

Overview of menu items in the Service Error Counter menu

Service Pro menu

General

NOTE!

General

NOTE!

Access code for the Service Pro menu

Overview of menu items in the Service Pro menu

Voltage limit values

Frequency limit values

NL-MONitor

Trip Time Delay

Reactive Power Mode

Freq dep. Power Red

Volt. dep. Power Red

Manual Power Reduction

Softstart

Voltage Fault Ride Through

DC-Injection

Ripple Control

I(delta gr.)F Compensation

Anti Islanding

Grid Quality Factor

Rate of change of frequency

Ramp Rate

Fail-Safe

Initial Start Time, Reconnect Time

Powerline Communication (Fronius Symo Advanced UL version)

DC Arc Fault Protection

"Advanced Grid Features": Reactive Power Mode

General information about reactive power mode

General information about reactive power mode

Potential operating range of the inverter in conjunction with reactive power

Overview of reactive power control options

Const. Cos φ

Const. Q Rel

Const. Q Abs

Ch Cos φ (P)

Ch Q (U)

Ch Q (P)

Lock-In / Lock-Out for characteristic operating mode

"Advanced Grid Features": GFDPR - Grid frequency-dependent power reduction P(f)

GFDPR - Function description

GFDPR - Function description

GFDPR - Application example On DisHyst

GFDPR - Application example On

Voltage Fault Ride Through - application example

GFDPR - Application example with "alt. Return Grad. 1” and “Alt. Ret. Grad Thr.”

GFDPR - Application example with "Return Gradient 2"

"Advanced Grid Features": GVDPR Grid voltage-dependent power reduction P(U)

GVDPR - Function description

GVDPR - Function description

"Advanced Grid Features": VFRT - Dynamic grid backup during temporary drops in grid voltage

I(delta gr.)F
Compensation