Product Guide - RED615

Relion 615 series

Line Differential Protection and ControlRED615Product Guide

Contents

1. Description.....................................................................32. Standard configurations.................................................33. Protection functions......................................................114. Application...................................................................115. Supported ABB solutions.............................................146. Control.........................................................................157. Measurements.............................................................168. Fault location................................................................169. Disturbance recorder....................................................1610. Event log.....................................................................1611. Recorded data............................................................1612. Condition monitoring ..................................................1613. Trip-circuit supervision.................................................1714. Self-supervision...........................................................1715. Current circuit supervision...........................................1716. Protection communication and supervision.................17

17. Access control............................................................1818. Inputs and outputs......................................................1819. Station communication................................................1920. Technical data.............................................................2221. Local HMI....................................................................5322. Mounting methods......................................................5423. IED case and IED plug-in unit......................................5424. Selection and ordering data.........................................5425. Accessories and ordering data....................................5526. Tools...........................................................................5527. Cyber security.............................................................5628. Terminal diagrams.......................................................5729. Certificates..................................................................6030. References..................................................................6031. Functions, codes and symbols....................................6232. Document revision history...........................................65

DisclaimerThe information in this document is subject to change without notice and should not be construed as a commitment by ABB. ABB assumes no responsibility for anyerrors that may appear in this document. Copyright 2014 ABB.All rights reserved.TrademarksABB and Relion are registered trademarks of the ABB Group. All other brand or product names mentioned in this document may be trademarks or registeredtrademarks of their respective holders.

Line Differential Protection and Control 1MRS756500 HRED615 Product version: 5.0

2 ABB

1. DescriptionRED615 is a phase-segregated two-end line differentialprotection and control IED (intelligent electronic device)designed for utility and industrial power systems, includingradial, looped and meshed distribution networks with orwithout distributed power generation. RED615 is alsodesigned for the protection of line differential applicationshaving a transformer within the protection zone. TheRED615s communicate between substations over a fibre-optic link or a galvanic pilot wire connection. RED615 is amember of ABBs Relion product family and part of its 615protection and control product series. The 615 series IEDsare characterized by their compactness and withdrawable-unit design. Re-engineered from the ground up, the 615series has been guided by the IEC 61850 standard forcommunication and interoperability of substation automationequipment.The IED provides unit type main protection for overhead linesand cable feeders in distribution networks. The IED alsofeatures current-based protection functions for remote back-up for down-stream protection IEDs and local back-up for theline differential main protection. Further, standardconfigurations B and C also include earth-fault protection.Standard configuration D includes directional overcurrent andvoltage based protection functions.The IED is adapted for the protection of overhead line andcable feeders in isolated neutral, resistance earthed,

compensated (impedance earthed) and solidly earthednetworks. Once the IED has been given the application-specific settings, it can directly be put into service.The 615 series IEDs support a range of communicationprotocols including IEC 61850 with GOOSE messaging, IEC61850-9-2 LE (except in RED615), IEC 60870-5-103,Modbus and DNP3. Profibus DPV1 communication protocolis supported by using the protocol converter SPA-ZC 302.

2. Standard configurationsRED615 is available in five alternative standard configurations.The standard signal configuration can be altered by means ofthe signal matrix or the graphical application functionality ofthe Protection and Control IED Manager PCM600. Further,the application configuration functionality of PCM600supports the creation of multi-layer logic functions utilizingvarious logical elements including timers and flip-flops. Bycombining protection functions with logic function blocks theIED configuration can be adapted to user specific applicationrequirements.The IED is delivered from the factory with default connectionsdescribed in the functional diagrams for binary inputs, binaryoutputs, function-to-function connections and alarm LEDs.The positive measuring direction of directional protectionfunctions is towards the outgoing feeder.

Line Differential Protection and Control 1MRS756500 HRED615 Product version: 5.0 Issued: 2014-01-24

Revision: H

ABB 3

RED615 AT REMOTE

END

CONDITION MONITORING AND SUPERVISION

COMMUNICATION

Protocols: IEC 61850-8-1 Modbus

IEC 60870-5-103 DNP3

Interfaces: Ethernet: TX (RJ45), FX (LC) Serial: Serial glass ber (ST), RS-485, RS-232/485 D-sub 9, IRIG-B

1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 01 0 1 0 0 0 1 1 0 0 1 1 0 0 1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 0

ALSO AVAILABLE

- Binary Signal Transfer function (BST)- Disturbance and fault recorder- Event log and recorded data- IED self-supervision - Local/Remote push button on LHMI- User management- Web HMI

ORAND

CONTROL AND INDICATION 1) MEASUREMENT

LINE DIFFERENTIAL PROTECTION AND CONTROL IED

PROTECTION LOCAL HMI

Analog interface types 1)

Current transformer

Voltage transformer1) Conventional transformer inputs

Object Ctrl 2) Ind 3)

CB

DC

ES1) Check availability of binary inputs/outputs

from technical documentation2) Control and indication function for

primary object3) Status indication function for primary object

1 -

2 3

1 2

STANDARDCONFIGURATION

REMARKS

Optionalfunction

No. ofinstances

Alternative function to be dened when ordering

OR

Io/Uo

Calculatedvalue

3

RL

ClearESCI

O

Conguration ASystemHMITimeAuthorization

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

With in-zone power transformer supportRED615

Sum of phase currents

I

- I, Io- Limit value supervision- Load prole record- Symmetrical components

4

-

A

PCSPCS

OPTSOPTM

2TCSTCM

2I2>46

3I>>>50P/51P

2Master Trip

Lockout relay94/86

3I>/Io>BF51BF/51NBF

3I2f>68

3I>51P-1

23I>>

51P-23dI>L87L

MCS 3IMCS 3I

BSTBST

PHIZHIZ

18MAPMAP

3I

IoI

3I

GUID-78F52211-9D37-4A2F-9527-CD61BDEA68A2 V1 EN

Figure 1. Functionality overview for standard configuration A


4 ABB

RED615 AT REMOTE

END


COMMUNICATION


IEC 60870-5-103 DNP3


1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 01 0 1 0 0 0 1 1 0 0 1 1 0 0 1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 0

ALSO AVAILABLE


ORAND





Current transformer



CB

DC




1 -

2 3

1 2


REMARKS

Optionalfunction

No. ofinstances


OR

Io/Uo

Calculatedvalue

3

RL

ClearESCI

O


RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A


- I, Io, Uo- Limit value supervision- Load prole record- Symmetrical components


COMMUNICATION


IEC 60870-5-103 DNP3


1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 01 0 1 0 0 0 1 1 0 0 1 1 0 0 1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 0

ALSO AVAILABLE


ORAND





Current transformer



CB

DC




1 -

2 3

1 2


REMARKS

Optionalfunction

No. ofinstances


OR

Io/Uo

Calculatedvalue

3

RL

ClearESCI

O


RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

With in-zone power transformer supportRED615 B

4

1

CBCMCBCM

3I>/Io>BF51BF/51NBF

OPTSOPTM

2TCSTCM

OI79

2I2>46

I2/I1>46PD

3Ith>F49F

3I>>>50P/51P

2Master Trip

Lockout relay94/86

2Io>67N-1

Io>>67N-2

Io>IEF67NIEF

3Uo>59G

Io>>51N-2

3I>51P-1

3I2f>68

3Yo>21YN

3Po>32N

OR

23I>>

51P-2MCS 3IMCS 3I

PCSPCS

BSTBST

3dI>L87L

Io>HA51NHA

OR

PHIZHIZ

18MAPMAP

3Ith>T49T

3I

Uo

Uo

Io

Io

Io

3I

GUID-6AB801FF-A43F-40D6-8D70-D27EF2F402B0 V1 EN

Figure 2. Functionality overview for standard configuration B


ABB 5

RED615 AT REMOTE

END


COMMUNICATION


IEC 60870-5-103 DNP3


1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 01 0 1 0 0 0 1 1 0 0 1 1 0 0 1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 0

ALSO AVAILABLE


ORAND





Current transformer



CB

DC




1 -

2 3

1 2


REMARKS

Optionalfunction

No. ofinstances


OR

Io/Uo

Calculatedvalue

3

RL

ClearESCI

O


RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A



COMMUNICATION


IEC 60870-5-103 DNP3


1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 01 0 1 0 0 0 1 1 0 0 1 1 0 0 1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 0

ALSO AVAILABLE


ORAND





Current transformer



CB

DC




1 -

2 3

1 2


REMARKS

Optionalfunction

No. ofinstances


OR

Io/Uo

Calculatedvalue

3

RL

ClearESCI

O


RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A


- I, Io- Limit value supervision- Load prole record- Symmetrical components

4

-

C

OI79

2Master Trip

Lockout relay94/86

Io>>51N-2

BSTBST

Io>HA51NHA

3I>/Io>BF51BF/51NBF

2I2>46

I2/I1>46PD

3Ith>F49F

3I>>>50P/51P

3I>51P-1

3I2f>68

23I>>

51P-23dI>L87L

3Ith>T49T

18MAPMAP

OPTSOPTM

2TCSTCM

MCS 3IMCS 3I

PCSPCS

CBCMCBCM

PHIZHIZ

Io>>>50N/51N

2Io>

51N-1

3I

Io

Io

Io

3I

GUID-C4999021-E1FE-4D55-AB91-FC7C6963501B V1 EN

Figure 3. Functionality overview for standard configuration C


6 ABB

RED615 AT REMOTE

END


COMMUNICATION


IEC 60870-5-103 DNP3


1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 01 0 1 0 0 0 1 1 0 0 1 1 0 0 1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 0

ALSO AVAILABLE


ORAND





CB

DC




1 -

2 3

1 2


REMARKS

Optionalfunction

No. ofinstances


OR

Io/Uo

Calculatedvalue

3

RL

ClearESCI

O


RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A



COMMUNICATION


IEC 60870-5-103 DNP3


1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 01 0 1 0 0 0 1 1 0 0 1 1 0 0 1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 0

ALSO AVAILABLE


ORAND





Current transformer



CB

DC




1 -

2 3

1 2


REMARKS

Optionalfunction

No. ofinstances


OR

Io/Uo

Calculatedvalue

3

RL

ClearESCI

O


RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A


- I, U, Io, Uo, P, Q, E, pf, f- Limit value supervision- Load prole record- RTD/mA measurement (optional)- Symmetrical components

D

3I>/Io>BF51BF/51NBF

OPTSOPTM

2TCSTCM

2I2>46

I2/I1>46PD

3Ith>F49F

3I>>>50P/51P

2Master Trip

Lockout relay94/86

2Io>67N-1

Io>>67N-2

Io>IEF67NIEF

Io>>51N-2

3Yo>21YN

3Po>32N

OR

MCS 3IMCS 3I

PCSPCS

BSTBST

CBCMCBCM

Io>HA51NHA

OR

3Ith>T49T

33U47O-

U159

3Uo>59G

4f>/f67-1

3I2f>68

3I>>67-2

2xRTD1xmA

3dI>L87L

PHIZHIZ

OI79

FUSEF60

PQM3IPQM3I

PQM3UPQM3V

PQMUPQMV

3I

Uo

Uo

Io

Io

Io

UL1

UL2

UL3

UL1UL2UL3

UL1UL2UL3

3I

Io

3I


Current transformer

Voltage transformer1) Conventional transformer inputs2) One of the ve inputs is reserved for

future applications

2)

4

5

GUID-F76822E6-DDB6-44F2-8704-5A5B3035BAFD V1 EN

Figure 4. Functionality overview for standard configuration D


ABB 7

RED615 AT REMOTE

END


COMMUNICATION


IEC 60870-5-103 DNP3


1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 01 0 1 0 0 0 1 1 0 0 1 1 0 0 1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 0

ALSO AVAILABLE


ORAND





CB

DC




1 -

2 3

1 2


REMARKS

Optionalfunction

No. ofinstances


OR

Io/Uo

Calculatedvalue

3

RL

ClearESCI

O


RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A



COMMUNICATION


IEC 60870-5-103 DNP3


1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 01 0 1 0 0 0 1 1 0 0 1 1 0 0 1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 0

ALSO AVAILABLE


ORAND





CB

DC




1 -

2 3

1 2


REMARKS

Optionalfunction

No. ofinstances


OR

Io/Uo

Calculatedvalue

3

RL

ClearESCI

O


RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A



Current sensor

Voltage sensor

1) Combi sensor inputs with conventionalIo input

Current transformer 1

3

3

- I, U, Io, Uo, P, Q, E, pf, f- Limit value supervision- Load prole record- Symmetrical components

E

3I>/Io>BF51BF/51NBF

OPTSOPTM

2TCSTCM

2I2>46

I2/I1>46PD

3Ith>F49F

3I>>>50P/51P

2Master Trip

Lockout relay94/86

2Io>67N-1

Io>>67N-2

Io>IEF67NIEF

Io>>51N-2

MCS 3IMCS 3I

PCSPCS

BSTBST

CBCMCBCM

3Yo>21YN

3Po>32N

OR

Io>HA51NHA

OR

3Ith>T49T

33U47O-

U159

3Uo>59G

4f>/f67-1

3I2f>68

3I>>67-2

3dI>L87L

PQM3IPQM3I

PQM3UPQM3V

PQMUPQMV

OI79

FUSEF60

3I

Io

Io

UL1

UL2

UL3

UL1UL2UL3

3I

Uo

Io

Io

3I

GUID-D0C7BD80-3FC0-448D-ACD4-D6123319339C V1 EN

Figure 5. Functionality overview for standard configuration E


8 ABB

Table 1. Standard configurations

Description Std. conf.Line differential protection and CB control ALine differential protection with directional earth-fault protection, CB condition monitoring and CB control BLine differential protection with non-directional earth-fault protection, CB condition monitoring and CB control CLine differential protection, directional overcurrent and directional earth-fault protection, phase-voltage and frequency basedprotection and measurement functions, CB condition monitoring, CB control and fault locator (optional) D

Line differential protection with directional overcurrent and directional earth-fault protection, phase-voltage and frequencybased protection and measurement functions, CB condition monitoring, CB control, sensor inputs for phase currents andphase voltages and fault locator (optional)

E


ABB 9

Table 2. Supported functionsFunction IEC 61850 A B C D EProtection1)Three-phase non-directional overcurrent protection, low stage PHLPTOC 1 1 1 Three-phase non-directional overcurrent protection, high stage PHHPTOC 2 2 2 Three-phase non-directional overcurrent protection,instantaneous stage PHIPTOC 1 1 1 1 1Three-phase directional overcurrent protection, low stage DPHLPDOC 2 2Three-phase directional overcurrent protection, high stage DPHHPDOC 1 1Non-directional earth-fault protection, low stage EFLPTOC 2 2) Non-directional earth-fault protection, high stage EFHPTOC 1 2) Non-directional earth-fault protection, instantaneous stage EFIPTOC 1 2) Directional earth-fault protection, low stage DEFLPDEF 2 2)3) 2 2)3) 2 4)5)Directional earth-fault protection, high stage DEFHPDEF 1 2)3) 1 2)3) 1 4)5)Admittance-based earth-fault protection 6) EFPADM (3) 2)3)6) (3) 2)3)6) (3) 2)5)6)Wattmetric-based earth-fault protection 6) WPWDE (3) 2)3)6) (3) 2)3)6) (3) 2)5)6)Transient/intermittent earth-fault protection INTRPTEF 1 7)8) 1 7)8) 1 5)8)Harmonics-based earth-fault protection 6) HAEFPTOC (1) 6)8) (1) 6)8) (1) 6)8) (1) 6)8)Non-directional (cross-country) earth-fault protection, usingcalculated Io EFHPTOC 1 4) 1 4) 1 4)Negative-sequence overcurrent protection NSPTOC 2 2 2 2 2Phase discontinuity protection PDNSPTOC 1 1 1 1Residual overvoltage protection ROVPTOV 3 3) 3 7) 3 5)Three-phase undervoltage protection PHPTUV 3 3Three-phase overvoltage protection PHPTOV 3 3Positive-sequence undervoltage protection PSPTUV 1 1Negative-sequence overvoltage protection NSPTOV 1 1Frequency protection FRPFRQ 4 4Three-phase thermal protection for feeders, cables anddistribution transformers T1PTTR 1 1 1 1Three-phase thermal overload protection for power transformers,two time constants T2PTTR 1 1 1 1Binary signal transfer BSTGGIO 1 1 1 1 1Circuit breaker failure protection CCBRBRF 1 9) 1 1 1 1Three-phase inrush detector INRPHAR 1 1 1 1 1Master trip TRPPTRC 2 2 2 2 2Multi-purpose protection 10) MAPGAPC 18 18 18 18 18Fault locator SCEFRFLO (1) (1)Line differential protection with in zone power transformer LNPLDF 1 1 1 1 1High impedance fault detection PHIZ 1 1 1 1 Power qualityCurrent total demand distortion CMHAI (1) 11) (1) 11)Voltage total harmonic distortion VMHAI (1) 11) (1) 11)Voltage variation PHQVVR (1) 11) (1) 11)Control Circuit-breaker control CBXCBR 1 1 1 1 1Disconnector control DCXSWI 2 2 2 2 2Earthing switch control ESXSWI 1 1 1 1 1Disconnector position indication DCSXSWI 3 3 3 3 3Earthing switch indication ESSXSWI 2 2 2 2 2Autoreclosing DARREC (1) (1) (1) (1)Condition monitoringCircuit-breaker condition monitoring SSCBR 1 1 1 1Trip circuit supervision TCSSCBR 2 2 2 2 2Current circuit supervision CCRDIF 1 1 1 1 1Fuse failure supervision SEQRFUF 1 1Protection communication supervision PCSRTPC 1 1 1 1 1


10 ABB

Table 2. Supported functions, continuedFunction IEC 61850 A B C D ERuntime counter for machines and devices MDSOPT 1 1 1 1 1MeasurementDisturbance recorder RDRE 1 1 1 1 1Load profile record LDPMSTA 1 1 1 1 1Three-phase current measurement CMMXU 1 1 1 1 1Sequence current measurement CSMSQI 1 1 1 1 1Residual current measurement RESCMMXU 1 1 1 1Three-phase voltage measurement VMMXU 1 1Residual voltage measurement RESVMMXU 1 1 Sequence voltage measurement VSMSQI 1 1Three-phase power and energy measurement PEMMXU 1 1RTD/mA measurement XRGGIO130 (1) Frequency measurement FMMXU 1 11, 2, ... = number of included instances() = optional

1) The instances of a protection function represent the number of identical protection function blocks available in the standard configuration.2) Io selectable by parameter, Io measured as default3) "Uo measured" is always used.4) Io selectable by parameter, "Io calculated" as default5) "Uo calculated" is always used.6) One of the following can be ordered as an option: admittance-based E/F, wattmetric-based E/F or harmonics-based E/F. The option is an addition to the existing E/F of the original

configuration. The optional E/F has also a predefined configuration in the IED. The optional E/F can be set on or off.7) Uo selectable by parameter, Uo measured as default8) "Io measured" is always used.9) "Io calculated" is always used.10) Multi-purpose protection is used, for example, for RTD/mA-based protection or analog GOOSE.11) Power quality option includes current total demand distortion, voltage total harmonic distortion and voltage variation.

3. Protection functionsThe IED offers two-stage phase-segregated line differentialprotection, phase overcurrent protection, negative phase-sequence overcurrent protection and circuit breaker failureprotection. Depending on the standard configuration chosen,the basic functionality can be extended by thermal overloadprotection, non-directional or directional overcurrentprotection, directional or non-directional earth-faultprotection, sensitive earth-fault protection, phasediscontinuity protection, transient/intermittent earth-faultprotection, residual overvoltage protection, phase-voltageand frequency based protection and three-pole multi-shotauto-reclose functions for overhead line feeders. For standardconfiguration B, D and E, admittance-based, wattmetric-based or harmonics-based earth-fault protection is offered asan option in addition to the directional earth-fault protection.The line differential protection function includes a stabilizedlow stage and an instantaneous high stage. The stabilized lowstage provides sensitive differential protection and remainsstable during, for example, current transformer saturationconditions. The low-stage operation can be restrained usingsecond harmonic detection if an out-of-zone powertransformer is to be energized. The instantaneous high stageoffers less sensitive differential protection but enables fastoperation during high fault currents. If there is an in-zonetransformer in the protection zone, then the vector group is

automatically compensated based on the winding types andclock number setting values.The operating time characteristic for the low stage can be setto definite time or inverse definite time mode. The direct inter-trip function ensures that both ends are alwayssimultaneously tripped, independent of the fault currentcontribution.

4. ApplicationRED615 can be used in a variety of applications requiring anabsolutely selective unit type protection system. The zone-of-protection of a line differential protection system is the feedersection defined by the location of the current transformers inthe local and the remote substation. RED615 can also beused for line differential protection if there is an in-zonetransformer in the protected feeder section.Combining horizontal GOOSE communication over a stationbus and binary signal transfer over the protectioncommunication link offers new application possibilitiesbeyond traditional line differential protection. One interestingapplication based on inter-substation signal transfer is loss-of-mains (LOM) protection in networks with distributedgeneration. The performance of the combination of binarysignal transfer and horizontal GOOSE communicationperformance as to speed, selectivity and reliability are hard tomatch with conventional loss-of-mains protection.


ABB 11

RED615 is the ideal IED for the protection of feeders innetwork configurations containing closed loops. Under normaloperating conditions the feeder loop is closed. The aim of theclosed loop is to secure the availability of power for the endusers. As a result of the closed loop configuration, any faultspot in the system will be fed with fault current from twodirections. Using plain overcurrent protection, eitherdirectional or non-directional, it is difficult to obtain fast andselective short circuit protection. With RED615 line differentialprotection IEDs the faulty part of the network can beselectively isolated, thus securing power distribution to thehealthy part of the network.The standard configuration E includes one conventionalresidual current (Io) input and three combi-sensor inputs forphase currents and phase voltages. The connection of thethree combi-sensors is made with RJ-45 type of connectors.Sensors offer certain benefits compared to conventionalcurrent and voltage instrument transformers, for example,

current sensors are not saturating at high currents, theyconsume less energy and they have a lower weight while involtage sensors the risk of ferro-resonance is eliminated. Thesensor inputs also enable the use of the IED in compactmedium voltage switchgears, such as ABBs UniGear Digital,SafeRing and SafePlus, with limited space for conventionalmeasuring transformers, thus requiring the use of sensortechnology. Further, the adapters also enable the use ofsensors with Twin-BNC connectors.Under certain operational circumstances, such asmaintenance of primary equipment or substation extensionprojects there will be a need for interconnecting networkparts, which normally are separated. To avoid major re-parameterization of the protection devices of the networkwhen the network topology is changed, line differentialprotection IEDs can be used to obtain absolutely selectivefeeder protection in looped networks.

3I

RED615Std. conf.

ANSI IEC

46

50P/51P

51BF/51NBF

51P-1/51P-2

87L

BST

MCS 3I

I2>

3I>>>

3I>/Io>BF

3I>/3I>>

3I>

BST

MCS 3I

A

3IRL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

RED615Std. conf.

ANSI IEC

46

50P/51P

51BF/51NBF

51P-1/51P-2

87L

BST

MCS 3I

I2>

3I>>>

3I>/Io>BF

3I>/3I>>

3I>

BST

MCS 3I

A

I

Protection communication

I

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

GUID-28763BDA-8E54-4716-9CDD-F2A208E79E25 V1 EN

Figure 6. Line differential protection for an interconnecting feeder between two primary distribution substations using standardconfiguration A

Line differential protection for an interconnecting feederbetween two primary distribution substations using standardconfiguration A. It additionally offers protection for a in-zone

power transformer, when available and located in theprotection zone.


12 ABB

Io

3I

3IRED615Std. conf.

ANSI IEC

46

49F/49T

50P/51P

51BF/51NBF

51N

87L

BST

MCS 3I

I2>

3Ith>F/3Ith>T

3I>>>

3I>/Io>BF

Io>

3I>

BST

MCS 3I

B/C

RED615Std. conf.

ANSI IEC

46

47O-/59

47U+/27

50P/51P

51BF/51NBF

67N-1/67N-2

87L

BST

MCS 3I

I2>

U2>/3U>

U1>>

3I>/Io>BF

Io>/Io>>

3I>

BST

MCS 3I

D3U Uo

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

Protectioncommunication

Io

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

GUID-3084D6C6-6067-4827-AA10-DAC1A772077C V1 EN

Figure 7. Line differential protection of a feeder using the standard configurations D and B or C

Line differential protection of a feeder using the standardconfigurations D and B or C. It additionally offers protection

for a in-zone power transformer, when available and locatedin the protection zone.

3IRED615Std. conf.

ANSI IEC

46

47O-/59

47U+/27

50P/51P

51BF/51NBF

67N-1/67N-2

87L

BST

I2>

U2>/3U>

U1>>

3I>/Io>BF

Io>/Io>>

3I>

BST

E

RED615Std. conf.

ANSI IEC

46

47O-/59

47U+/27

50P/51P

51BF/51NBF

67N-1/67N-2

87L

BST

I2>

U2>/3U>

U1>>

3I>/Io>BF

Io>/Io>>

3I>

BST

E

Io

Protectioncommunication

Io

3I

3U

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

3U

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

GUID-6802EC2A-DC22-44E6-8BD2-DF7DCEAAEBA0 V1 EN

Figure 8. Line differential protection of a feeder using the standard configuration E


ABB 13

Line differential protection of a feeder using the standardconfiguration E, in which current sensors (Rogowski coil) andvoltage sensors (voltage divider) are used for themeasurements. It additionally offers protection for a in-zonepower transformer, when available and located in the

protection zone. The standard configuration E has been pre-configured especially for ABB switchgears, for example,UniGear Digital. The use of this configuration is not restrictedfor this purpose only.

5. Supported ABB solutionsABBs 615 series protection and control IEDs together withthe grid automation controller COM600 constitute a genuineIEC 61850 solution for reliable power distribution in utility andindustrial power systems. To facilitate and streamline thesystem engineering, ABB's IEDs are supplied withconnectivity packages. The connectivity packages include acompilation of software and IED-specific information,including single-line diagram templates and a full IED datamodel. The data model also includes event and parameterlists. With the connectivity packages, the IEDs can be readilyconfigured using PCM600 and integrated with the gridautomation controller COM600 or the network control andmanagement system MicroSCADA Pro.The 615 series IEDs offer native support for the IEC 61850standard also including binary and analog horizontal GOOSEmessaging. In addition, process bus with sampled values ofanalog phase voltages is supported. Compared to traditionalhard-wired, inter-device signaling, peer-to-peercommunication over a switched Ethernet LAN offers anadvanced and versatile platform for power system protection.Among the distinctive features of the protection systemapproach, enabled by the full implementation of the IEC61850 substation automation standard, are fastcommunication capability, continuous supervision of theintegrity of the protection and communication system, and aninherent flexibility regarding reconfiguration and upgrades.At substation level, COM600 uses the data content of the bay-level IEDs to enhance substation level functionality. COM600features a Web browser-based HMI, which provides a

customizable graphical display for visualizing single-line mimicdiagrams for switchgear bay solutions. The SLD feature isespecially useful when 615 series IEDs without the optionalsingle-line diagram feature are used. The Web HMI ofCOM600 also provides an overview of the whole substation,including IED-specific single-line diagrams, which makesinformation easily accessible. Substation devices andprocesses can also be remotely accessed through the WebHMI, which improves personnel safety.In addition, COM600 can be used as a local data warehousefor the substation's technical documentation and for thenetwork data collected by the IEDs. The collected networkdata facilitates extensive reporting and analyzing of networkfault situations, by using the data historian and event handlingfeatures of COM600. The history data can be used foraccurate monitoring of process and equipment performance,using calculations based on both real-time and history values.A better understanding of the process dynamics is achievedby combining time-based process measurements withproduction and maintenance events.COM600 can also function as a gateway and providesseamless connectivity between the substation IEDs andnetwork-level control and management systems, such asMicroSCADA Pro and System 800xA.GOOSE Analyzer interface in COM600 enables the followingand analyzing the horizontal IEC 61850 application duringcommissioning and operation at station level. It logs allGOOSE events during substation operation to enableimproved system supervision.

Table 3. Supported ABB solutions

Product VersionGrid automation controller COM600 4.0 SP1 or laterMicroSCADA Pro SYS 600 9.3 FP2 or laterSystem 800xA 5.1 or later


14 ABB

PCM600Ethernet switch

Utility: IEC 60870-5-104Industry: OPC

COM600Web HMI

ABBMicroSCADA Pro/

System 800xA

Analog and binary horizontal GOOSE communication IEC 61850

PCM600Ethernet switch

COM600Web HMI

Analog and binary horizontal GOOSE communication IEC 61850

GUID-4D002AA0-E35D-4D3F-A157-01F1A3044DDB V1 EN

Figure 9. ABB power system example using Relion IEDs, Grid Automation controller COM600 and MicroSCADA Pro/System 800xA

6. ControlRED615 integrates functionality for the control of a circuitbreaker via the front panel HMI or by means of remotecontrols. In addition to the circuit-breaker control the IEDfeatures two control blocks which are intended for motor-operated control of disconnectors or circuit breaker truck andfor their position indications. Further, the IED offers onecontrol block which is intended for motor-operated control ofone earthing switch control and its position indication.Two physical binary inputs and two physical binary outputsare needed in the IED for each controllable primary devicetaken into use. Depending on the chosen standardconfiguration of the IED the number of unused binary inputsand binary outputs varies. Further, some standardconfigurations also offer optional hardware modules thatincrease the number of available binary inputs and outputs.In case the amount of available binary inputs and/or outputsof the chosen standard configuration is not sufficient, thefollowing alternatives are recommended:

To modify the chosen standard configuration of the IED inorder to release some binary inputs or binary outputs whichhave originally been configured for other purposes, whenapplicable.

To integrate an external input or output module forexample, RIO600 to the IED. The binary inputs and outputsof the external I/O module can be used for the less timecritical binary signals of the application. The integrationenables releasing of some initially reserved binary inputsand outputs of the IED in the standard configuration.

The suitability of the binary outputs of the IED which havebeen selected for controlling of primary devices should becarefully verified, for example the make and carry as well asthe breaking capacity. In case the requirements for thecontrol-circuit of the primary device are not met, the use ofexternal auxiliary relays should to be considered.The optional large graphical LCD of the IED's HMI includes asingle-line diagram (SLD) with position indication for therelevant primary devices. Interlocking schemes required by


ABB 15

the application are configured using the signal matrix or theapplication configuration functionality of PCM600.

7. MeasurementsThe IED continuously measures the phase currents, thesymmetrical components of the currents and the residualcurrent. If the IED includes voltage measurements it alsomeasures the residual voltage. The IED also calculates thedemand value of the current over a user-selectable, pre-settime frame, the thermal overload of the protected object, andthe phase unbalance based on the ratio between the negative-sequence and positive-sequence current.Furthermore, the IED monitors the phase differential, bias andremote-end phase currents.The values measured can be accessed locally via the userinterface on the IED front panel or remotely via thecommunication interface of the IED. The values can also beaccessed locally or remotely using the Web browser-baseduser interface.The IED is provided with a load profile recorder. The loadprofile feature stores the historical load data captured at aperiodical time interval (demand interval). The records are inCOMTRADE format.

8. Fault locationRED615 features an optional impedance-measuring faultlocation function suitable for locating short-circuits in radialdistribution systems. Earth faults can be located in effectivelyand low-resistance earthed networks. Under circumstanceswhere the fault current magnitude is at least of the sameorder of magnitude or higher than the load current, earthfaults can also be located in isolated neutral distributionnetworks. The fault location function identifies the type of thefault and then calculates the distance to the fault point. Anestimate of the fault resistance value is also calculated. Theestimate provides information about the possible fault causeand the accuracy of the estimated distance to the fault point.

9. Disturbance recorderThe IED is provided with a disturbance recorder with up to 12analog and 64 binary signal channels. The analog channelscan be set to record either the waveform or the trend of thecurrents and voltages measured.The analog channels can be set to trigger the recordingfunction when the measured value falls below, or exceeds,the set values. The binary signal channels can be set to starta recording either on the rising or the falling edge of thebinary signal or on both.By default, the binary channels are set to record external orinternal IED signals, for example, the start or trip signals ofthe IED stages, or external blocking or control signals. Binary

IED signals, such as protection start and trip signals, or anexternal IED control signal via a binary input, can be set totrigger the recording. The recorded information is stored in anon-volatile memory and can be uploaded for subsequentfault analysis.

10. Event logTo collect sequence-of-events information, the IED has a non-volatile memory with a capacity of storing 1024 events withassociated time stamps. The non-volatile memory retains itsdata also in case the IED temporarily loses its auxiliary supply.The event log facilitates detailed pre- and post-fault analysesof feeder faults and disturbances. The increased capacity toprocess and store data and events in the IED offersprerequisites to support the growing information demand offuture network configurations.The sequence-of-events information can be accessed eitherlocally via the user interface on the IED front panel, orremotely via the communication interface of the IED. Theinformation can also be accessed using the Web browser-based user interface, either locally or remotely.

11. Recorded dataThe IED has the capacity to store the records of the 128latest fault events. The records enable the user to analyze thepower system events. Each record includes the phase,differential and bias current values, time stamp, etc. The faultrecording can be triggered by the start signal or the trip signalof a protection block, or by both. The available measurementmodes include DFT, RMS and peak-to-peak. Fault recordsstore IED measurement values at the moment when anyprotection function starts. In addition, the maximum demandcurrent with time stamp is separately recorded. By default,the records are stored in the nonvolatile memory.

12. Condition monitoringThe condition monitoring functions of the IED constantlymonitors the performance and the condition of the circuitbreaker. The monitoring comprises the spring charging time,SF6 gas pressure, the travel time and the inactivity time of thecircuit breaker.The monitoring functions provide operational circuit breakerhistory data, which can be used for scheduling preventivecircuit breaker maintenance.In addition, the IED includes a runtime counter for monitoringof how many hours a protected device has been in operationthus enabling scheduling of time-based preventivemaintenance of the device.


16 ABB

13. Trip-circuit supervisionThe trip-circuit supervision continuously monitors theavailability and operability of the trip circuit. It provides open-circuit monitoring both when the circuit breaker is in itsclosed and in its open position. It also detects loss of circuit-breaker control voltage.

14. Self-supervisionThe IEDs built-in self-supervision system continuouslymonitors the state of the IED hardware and the operation ofthe IED software. Any fault or malfunction detected is usedfor alerting the operator.A permanent IED fault blocks the protection functions toprevent incorrect operation.

15. Current circuit supervisionThe IED includes current circuit supervision. Current circuitsupervision is used for detecting faults in the currenttransformer secondary circuits. On detecting of a fault thecurrent circuit supervision function activates an alarm LEDand blocks the line differential protection and negativesequence overcurrent protection functions to avoidunintended operation. The current circuit supervision functioncalculates the sum of the phase currents from the protectioncores and compares the sum with the measured singlereference current from a core balance current transformer orfrom separate cores in the phase current transformers

16. Protection communication and supervisionThe communication between the IEDs is enabled by means ofa dedicated fibre-optic communication channel. 1300 nmmulti-mode or single-mode fibres with LC connectors areused for line differential communication. The channel is usedfor transferring the phase segregated current value databetween the IEDs. The current phasors from the two IEDs,geographically located apart from each other, must be timecoordinated so that the current differential algorithm can beexecuted correctly. The so called echo method is used fortime synchronization. No external devices such as GPSclocks are thereby needed for the line differential protectioncommunication.As an option to the fibre-optic communication link a galvanicconnection over a pilot wire link composed of a twisted paircable and RPW600 link-end communication modems can be

established. The optional pilot wire communication link is alsoan ideal and cost efficient retrofit solution forelectromechanical line differential protection installations.Compared to conventional combined sequence linedifferential protection solutions with analog pilot wirecommunication, RED615 IEDs in combination with RPW600communication modems offer a modern phase-segregatedline differential protection solution over existing pilot wirecables.The pilot wire link supports the same protection andcommunication functionality as the fibre-optic link. The qualityof service (QoS) is indicated by the modems and thecommunication link is continuously supervised by the IED.The RPW600 modem offers a 5 kV (RMS) level of isolationbetween the pilot wire terminals and ground. The RPW600modems (master and follower) are galvanically connected toeither end of the pilot wire and optically connected to theIEDs using short optical single-mode cables. Using 0.8 mm2twisted pair cables pilot wire link distances up to 8 km aretypically supported. However, twisted pair pilot wire cables ingood conditions may support even longer distances to becovered. The length of the supported pilot wire link alsodepends on the noise environment in the installation. Shouldthe need arise to replace the pilot wire cables with fibre-opticcables, the single mode fibre-optic LC connectors of the IEDscan be utilized for direct connection of the fibre-opticcommunication link.Apart from the continued protection communication, thecommunication channel can also be used for binary signaltransfer (BST) that is, transferring of user configurable binaryinformation between the IEDs. There are a total of eight BSTsignals available for user definable purposes. The BST signalscan originate from the IEDs binary inputs or internal logics,and be assigned to the remote IEDs binary outputs orinternal logics.The protection communication supervision continuouslymonitors the protection communication link. The IEDimmediately blocks the line differential protection function incase that severe interference in the communication link,risking the correct operation of the function, is detected. Analarm signal will eventually be issued if the interference,indicating permanent failure in the protection communication,persists. The two high-set stages of the overcurrentprotection are further by default released.


ABB 17

RED615 RED615

Fibre-optic line differential communication link

Protection communication and supervisionBinary signal transfer

GUID-8CE71CC9-F0EA-4BE9-B693-173CAEA9FA58 V2 EN

Figure 10. Fibre-optic protection communication link

RED615 RED615

Pilot wire line differential communication link

Protection communication and supervisionBinary signal transfer

RPW600modem

RPW600modem

GUID-12C57326-6CB9-4FA9-B9F4-3D8F21015DCF V2 EN

Figure 11. Pilot wire protection communication link

17. Access controlTo protect the IED from unauthorized access and to maintaininformation integrity, the IED is provided with a four-level, role-based authentication system with administrator-programmable individual passwords for the viewer, operator,engineer and administrator level. The access control appliesto the front-panel user interface, the Web browser-baseduser interface and PCM600.

18. Inputs and outputsDepending on the standard configuration selected, the IED isequipped with three phase-current inputs and one residual-current input for non-directional earth-fault protection andcurrent circuit supervision, or three phase-current inputs, oneresidual-current input and one residual voltage input fordirectional earth-fault protection and current circuitsupervision.The standard configuration E includes one conventionalresidual current (Io 0.2/1 A) input and three sensor inputs forthe direct connection of three combi-sensors with RJ-45connectors. As an alternative to combi-sensors, separatecurrent and voltage sensors can be utilized using adapters.

Furthermore, the adapters also enable the use of sensorswith Twin-BNC connectors.The phase-current inputs are rated 1/5 A. Two optionalresidual-current inputs are available, that is, 1/5 A or 0.2/1 A.The 0.2/1 A input is normally used in applications requiringsensitive earth-fault protection and featuring core-balancecurrent transformers. The residual-voltage input covers therated voltages 60-210 V.The phase-current input 1 A or 5 A, the residual-current input1 A or 5 A, alternatively 0.2 A or 1 A, and the rated voltage ofthe residual voltage input are selected in the IED software. Inaddition, the binary input thresholds 16176 V DC areselected by adjusting the IEDs parameter settings.All binary inputs and outputs contacts are freely configurablewith the signal matrix or application configuration functionalityof PCM600.Please refer to the Input/output overview table and theterminal diagrams for more detailed information about theinputs and outputs.


18 ABB

Table 4. Input/output overview

Std. conf. Order code digit Analog channels Binary channels 5-6 7-8 CT VT Combi

sensorBI BO RTD mA

A ACAD 4 - - 12 4 PO + 6 SO - -AF 4 - - 18 4 PO + 9 SO - -

B AA / ABAC 4 1 - 11 4 PO + 6 SO - -AE 4 1 - 17 4 PO + 9 SO - -

C ACAD 4 - - 12 4 PO + 6 SO - -AF 4 - - 18 4 PO + 9 SO - -

DFE / FF AD 4 5 - 12 4 PO + 6 SO 2 1AE / AF AG 4 5 - 16 4 PO + 6 SO - -

E DA AH 1 - 3 8 4 PO + 6 SO - -

19. Station communicationThe IED supports a range of communication protocolsincluding IEC 61850, Modbus and DNP3. Profibus DPV1communication protocol is supported with using the protocolconverter SPA-ZC 302. Operational information and controlsare available through these protocols. However, somecommunication functionality, for example, horizontalcommunication between the IEDs, is only enabled by the IEC61850 communication protocol.The IEC 61850 communication implementation supportsmonitoring and control functions. Additionally, parametersettings, disturbance recordings and fault records can beaccessed using the IEC 61850 protocol. Disturbancerecordings are available to any Ethernet-based application inthe standard COMTRADE file format. The IED supports

simultaneous event reporting to five different clients on thestation bus.The IED can send binary and analog signals to other IEDs (socalled horizontal communication) using the IEC 61850-8-1GOOSE (Generic Object Oriented Substation Event) profile.Binary GOOSE messaging can, for example, be employed forprotection and interlocking-based protection schemes. TheIED meets the GOOSE performance requirements for trippingapplications in distribution substations, as defined by the IEC61850 standard. The IED also supports the sending andreceiving of analog values using GOOSE messaging. AnalogGOOSE messaging enables easy transfer of analogmeasurement values over the station bus, thus facilitating forexample sharing of RTD input values, such as surroundingtemperature values, to other IED applications.


ABB 19

Managed Ethernet switchwith RSTP support

Managed Ethernet switchwith RSTP support

Client BClient A

Network ANetwork B

GUID-AB81C355-EF5D-4658-8AE0-01DC076E519C V4 EN

Figure 12. Self-healing Ethernet ring solution

The IED offers an optional second Ethernet bus to enable thecreation of a self-healing Ethernet ring topology. Thecommunication module including two galvanic RJ-45 portsenables the creation of a cost efficient communication ringusing CAT 5 STP cables and a managed switch with (RSTP)support. The managed switch controls the consistency of theloop, routes the data and corrects the data flow in case of acommunication disturbance. The IEDs in the ring topology actas unmanaged switches forwarding unrelated data traffic. TheEthernet ring solution supports the connection of up to thirty615 series IEDs. If more than 30 IEDs are to be connected, itis recommended that the network is split into several ringswith no more than 30 IEDs per ring.The self-healing Ethernet ring solution avoids single point offailure concerns and improves the reliability of thecommunication. The solution can be applied for the Ethernet-based IEC 61850, Modbus and DNP3 protocols.All communication connectors, except for the front portconnector, are placed on integrated optional communicationmodules. The IED can be connected to Ethernet-basedcommunication systems via the RJ-45 connector (100Base-TX). If connection to a RS-485 network is required, a 9-pinscrew-terminal connector, an optional 9-pin D-sub connectoror an optional ST-type glass-fibre connector can be used.

Modbus implementation supports RTU, ASCII and TCPmodes. Besides standard Modbus functionality, the IEDsupports retrieval of time-stamped events, changing theactive setting group and uploading of the latest fault records.If a Modbus TCP connection is used, five clients can beconnected to the IED simultaneously. Further, Modbus serialand Modbus TCP can be used in parallel, and if required bothIEC 61850 and Modbus protocols can be run simultaneously.The IEC 60870-5-103 implementation supports two parallelserial bus connections to two different masters. Besidesbasic standard functionality, the IED supports changing of theactive setting group and uploading of disturbance recordingsin IEC 60870-5-103 format.DNP3 supports both serial and TCP modes for connection upto five masters. Changing of the active setting and readingfault records are supported. DNP serial and DNP TCP can beused in parallel. If required, both IEC 61850 and DNPprotocols can be run simultaneously.

When the IED uses the RS-485 bus for the serialcommunication, both two- and four wire connections aresupported. Termination and pull-up/down resistors can beconfigured with jumpers on the communication card soexternal resistors are not needed.


20 ABB

The IED supports the following time synchronization methodswith a time-stamping resolution of 1 ms.Ethernet-based SNTP (Simple Network Time Protocol)

With special time synchronization wiring IRIG-B (Inter-Range Instrumentation Group - Time Code

Format B)

Remote-end station time reference Line differential

In addition, the IED supports time synchronization via thefollowing serial communication protocols. Modbus DNP3 IEC 60870-5-103

Table 5. Supported station communication interfaces and protocols

Interfaces/Protocols Ethernet Serial100BASE-TX RJ-45 RS-232/RS-485 Fibre-optic ST

IEC 61850-8-1 - -MODBUS RTU/ASCII - MODBUS TCP/IP - -DNP3 (serial) - DNP3 TCP/IP - -IEC 60870-5-103 -

= Supported


ABB 21

20. Technical data

Table 6. Dimensions

Description Value Width frame 177 mm

case 164 mmHeight frame 177 mm (4U)

case 160 mmDepth 201 mm (153 + 48 mm)Weight complete IED 4.1 kg

plug-in unit only 2.1 kg

Table 7. Power supply

Description Type 1 Type 2Nominal auxiliary voltage Un 100, 110, 120, 220, 240 V AC, 50 and 60 Hz 24, 30, 48, 60 V DC

48, 60, 110, 125, 220, 250 V DCMaximum interruption time in the auxiliaryDC voltage without resetting the IED

50 ms at Un

Auxiliary voltage variation 38...110% of Un (38...264 V AC) 50...120% of Un (12...72 V DC)80...120% of Un (38.4...300 V DC)

Start-up threshold 19.2 V DC (24 V DC * 80%)Burden of auxiliary voltage supply underquiescent (Pq)/operating condition

DC < 12.0 W (nominal)/< 18.0 W (max)AC< 16.0 W (nominal)/< 21.0W (max)

DC < 12.0 W (nominal)/< 18.0 W (max)

Ripple in the DC auxiliary voltage Max 15% of the DC value (at frequency of 100 Hz)Fuse type T4A/250 V

Table 8. Energizing inputs

Description ValueRated frequency 50/60 HzCurrent inputs Rated current, In 1/5 A1)

Thermal withstand capability: Continuously 4 A 20 A For 1 s 100 A 500 ADynamic current withstand: Half-wave value 250 A 1250 AInput impedance

Table 9. Binary inputs

Description ValueOperating range 20% of the rated voltageRated voltage 24...250 V DCCurrent drain 1.6...1.9 mAPower consumption 31.0...570.0 mWThreshold voltage 16...176 V DCReaction time

Table 13. Single-pole power output relays

Description ValueRated voltage 250 V AC/DCContinuous contact carry 8AMake and carry for 3.0 s 15 AMake and carry for 0.5 s 30 ABreaking capacity when the control-circuit time constant L/R

Table 18. Degree of protection of flush-mounted IED

Description ValueFront side IP 54Rear side, connection terminals IP 20

Table 19. Environmental conditions

Description ValueOperating temperature range -25...+55C (continuous)Short-time service temperature range -40...+70C (

Table 20. Electromagnetic compatibility tests

Description Type test value Reference1 MHz/100 kHz burst disturbance test IEC 61000-4-18

IEC 60255-22-1, class IIIIEEE C37.90.1-2002

Common mode 2.5 kV Differential mode 2.5 kV 3 MHz, 10 MHz and 30 MHz burst disturbancetest

IEC 61000-4-18IEC 60255-22-1, class III

Common mode 2.5 kV Electrostatic discharge test IEC 61000-4-2

IEC 60255-22-2IEEE C37.90.3-2001

Contact discharge 8 kV Air discharge 15 kV Radio frequency interference test 10 V (rms)

f = 150 kHz...80 MHzIEC 61000-4-6IEC 60255-22-6, class III

10 V/m (rms)f = 80...2700 MHz

IEC 61000-4-3IEC 60255-22-3, class III

10 V/mf = 900 MHz

ENV 50204IEC 60255-22-3, class III

20 V/m (rms)f = 80...1000 MHz

IEEE C37.90.2-2004

Fast transient disturbance test IEC 61000-4-4IEC 60255-22-4IEEE C37.90.1-2002

All ports 4 kV Surge immunity test IEC 61000-4-5

IEC 60255-22-5 Communication 1 kV, line-to-earth Other ports 4 kV, line-to-earth

2 kV, line-to-line

Power frequency (50 Hz) magnetic fieldimmunity test

IEC 61000-4-8

Continuous 1...3 s

300 A/m1000 A/m

Pulse magnetic field immunity test 1000 A/m6.4/16 s

IEC 61000-4-9

Damped oscillatory magnetic field immunity test IEC 61000-4-10 2 s 100 A/m 1 MHz 400 transients/s Voltage dips and short interruptions 30%/10 ms

60%/100 ms60%/1000 ms>95%/5000 ms

IEC 61000-4-11


26 ABB

Table 20. Electromagnetic compatibility tests, continuedDescription Type test value ReferencePower frequency immunity test Binary inputs only IEC 61000-4-16

IEC 60255-22-7, class A Common mode 300 V rms Differential mode 150 V rms Conducted common mode disturbances 15 Hz...150 kHz

Test level 3 (10/1/10 V rms)IEC 61000-4-16

Emission tests EN 55011, class AIEC 60255-25

Conducted 0.15...0.50 MHz

Table 23. Environmental tests

Description Type test value ReferenceDry heat test 96 h at +55C

16 h at +70C1)IEC 60068-2-2

Dry cold test 96 h at -25C 16 h at -40C

IEC 60068-2-1

Damp heat test 6 cycles (12 h + 12 h) at +25C+55C,humidity >93%

IEC 60068-2-30

Change of temperature test 5 cycles (3 h + 3 h)at -25C...+55C

IEC60068-2-14

Storage test 96 h at -40C 96 h at +85C

IEC 60068-2-1IEC 60068-2-2

1) For IEDs with an LC communication interface the maximum operating temperature is +70oC

Table 24. Product safety

Description ReferenceLV directive 2006/95/ECStandard EN 60255-27 (2005)

EN 60255-1 (2009)

Table 25. EMC compliance

Description ReferenceEMC directive 2004/108/ECStandard EN 50263 (2000)

EN 60255-26 (2007)

Table 26. RoHS compliance

DescriptionComplies with RoHS directive 2002/95/EC


28 ABB

Protection functions

Table 27. Three-phase non-directional overcurrent protection (PHxPTOC)

Characteristic ValueOperation accuracy Depending on the frequency of the measured current: fn 2 Hz

PHLPTOC 1.5% of the set value or 0.002 InPHHPTOCandPHIPTOC

1.5% of set value or 0.002 In(at currents in the range of 0.110 In)5.0% of the set value(at currents in the range of 1040 In)

Start time 1)2) Minimum Typical MaximumPHIPTOC:IFault = 2 set Start valueIFault = 10 set Start value

16 ms 11 ms

19 ms 12 ms

23 ms 14 ms

PHHPTOC and PHLPTOC:IFault = 2 x set Start value

23 ms

26 ms

29 ms

Reset time Typically 40 msReset ratio Typically 0.96Retardation time

Table 28. Three-phase non-directional overcurrent protection (PHxPTOC) main settings

Parameter Function Value (Range) StepStart Value PHLPTOC 0.05...5.00 In 0.01

PHHPTOC 0.10...40.00 In 0.01PHIPTOC 1.00...40.00 In 0.01

Time multiplier PHLPTOC 0.05...15.00 0.01PHHPTOC 0.05...15.00 0.01

Operate delay time PHLPTOC 40...200000 ms 10PHHPTOC 40...200000 ms 10PHIPTOC 20...200000 ms 10

Operating curve type1) PHLPTOC Definite or inverse timeCurve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19

PHHPTOC Definite or inverse timeCurve type: 1, 3, 5, 9, 10, 12, 15, 17

PHIPTOC Definite time1) For further reference, see Operation characteristics table


30 ABB

Table 29. Three-phase directional overcurrent protection (DPHxPDOC)

Characteristic ValueOperation accuracy Depending on the frequency of the current/voltage measured: fn 2 Hz

DPHLPDOC Current:1.5% of the set value or 0.002 InVoltage:1.5% of the set value or 0.002 UnPhase angle: 2

DPHHPDOC Current:1.5% of the set value or 0.002 In(at currents in the range of 0.110 In)5.0% of the set value(at currents in the range of 1040 In)Voltage:1.5% of the set value or 0.002 UnPhase angle: 2

Start time1)2) Minimum Typical MaximumIFault = 2.0 set Start value 39 ms 43 ms 47 ms


Table 31. Non-directional earth-fault protection (EFxPTOC)


EFLPTOC 1.5% of the set value or 0.002 InEFHPTOCandEFIPTOC

1.5% of set value or 0.002 In(at currents in the range of 0.110 In)5.0% of the set value(at currents in the range of 1040 In)

Start time 1)2) Minimum Typical MaximumEFIPTOC:IFault = 2 set Start valueIFault = 10 set Start value

16 ms11 ms

19 ms12 ms

23 ms14 ms

EFHPTOC and EFLPTOC:IFault = 2 set Start value

23 ms

26 ms

29 ms


Table 33. Directional earth-fault protection (DEFxPDEF)


DEFLPDEF Current:1.5% of the set value or 0.002 InVoltage1.5% of the set value or 0.002 UnPhase angle:2

DEFHPDEF Current:1.5% of the set value or 0.002 In(at currents in the range of 0.110 In)5.0% of the set value(at currents in the range of 1040 In)Voltage:1.5% of the set value or 0.002 UnPhase angle:2

Start time 1)2) Minimum Typical MaximumDEFHPDEFIFault = 2 set Start value

42 ms

46 ms

49 ms

DEFLPDEFIFault = 2 set Start value

58 ms 62 ms 66 ms


Table 34. Directional earth-fault protection (DEFxPDEF) main settings

Parameter Function Value (Range) StepStart Value DEFLPDEF 0.010...5.000 In 0.005

DEFHPDEF 0.10...40.00 In 0.01Directional mode DEFLPDEF and DEFHPDEF 1 = Non-directional

2 = Forward3 = Reverse

Time multiplier DEFLPDEF 0.05...15.00 0.01DEFHPDEF 0.05...15.00 0.01

Operate delay time DEFLPDEF 60...200000 ms 10DEFHPDEF 40...200000 ms 10

Operating curve type1) DEFLPDEF Definite or inverse timeCurve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19

DEFHPDEF Definite or inverse timeCurve type: 1, 3, 5, 15, 17

Operation mode DEFLPDEF and DEFHPDEF 1 = Phase angle2 = IoSin3 = IoCos4 = Phase angle 805 = Phase angle 88

1) For further reference, refer to the Operating characteristics table

Table 35. Admittance-based earth-fault protection (EFPADM)

Characteristic ValueOperation accuracy1) At the frequency f = fn

1.0% or 0.01 mS(In range of 0.5...100 mS)

Start time2) Minimum Typical Maximum56 ms 60 ms 64 ms

Reset time 40 msOperate time accuracy 1.0% of the set value of 20 msSuppression of harmonics -50 dB at f = n fn, where n = 2, 3, 4, 5,

1) Uo = 1.0 Un2) Includes the delay of the signal output contact. Results based on statistical distribution of 1000 measurements.


34 ABB

Table 36. Admittance-based earth-fault protection (EFPADM) main settings

Parameter Function Value (Range) StepVoltage start value EFPADM 0.01...2.00 Un 0.01Directional mode EFPADM 1 = Non-directional

2 = Forward3 = Reverse

Operation mode EFPADM 1 = Yo2 = Go3 = Bo4 = Yo, Go5 = Yo, Bo6 = Go, Bo7 = Yo, Go, Bo

Operate delay time EFPADM 60...200000 ms 10Circle radius EFPADM 0.05...500.00 mS 0.01Circle conductance EFPADM -500.00...500.00 mS 0.01Circle susceptance EFPADM -500.00...500.00 mS 0.01Conductance forward EFPADM -500.00...500.00 mS 0.01Conductance reverse EFPADM -500.00...500.00 mS 0.01Conductance tilt Ang EFPADM -30...30 1Susceptance forward EFPADM -500.00...500.00 mS 0.01Susceptance reverse EFPADM -500.00...500.00 mS 0.01Susceptance tilt Ang EFPADM -30...30 1

Table 37. Wattmetric based earth-fault protection (WPWDE)


Current and voltage:1.5% of the set value or 0.002 InPower:3% of the set value or 0.002 Pn

Start time 1)2) Typically 63 msReset time Typically 40 msReset ratio Typically 0.96Operate time accuracy in definite time mode 1.0% of the set value or 20 msOperate time accuracy in IDMT mode 5.0% of the set value or 20 msSuppression of harmonics -50 dB at f = n fn, where n=2,3,4,5,

1) Io varied during the test. Uo = 1.0 Un = phase to earth voltage during earth-fault in compensated or un-earthed network. The residual power value before fault = 0.0 pu, f n = 50 Hz,results based on statistical distribution of 1000 measurement.

2) Includes the delay of the signal output contact.


ABB 35

Table 38. Wattmetric based earth-fault protection (WPWDE) main settings

Parameter Function Value (Range) StepDirectional mode WPWDE 2 = Forward

3 = Reverse

Current start value WPWDE 0.010...5.000 In 0.001Voltage start value WPWDE 0.010...1.000 Un 0.001Power start value WPWDE 0.003...1.000 Pn 0.001Reference power WPWDE 0.050...1.000 Pn 0.001Characteristic angle WPWDE -179...180 1Time multiplier WPWDE 0.05...2.00 0.01Operating curve type WPWDE Definite or inverse time

Curve type: 5, 15, 20Operate delay time WPWDE 60...200000 ms 10Min operate current WPWDE 0.010...1.000 In 0.001Min operate voltage WPWDE 0.01...1.00 Un 0.01

Table 39. Transient/intermittent earth-fault protection (INTRPTEF)

Characteristic ValueOperation accuracy (Uo criteria with transient protection) Depending on the frequency of the current measured: fn 2 Hz

1.5% of the set value or 0.002 x UoOperate time accuracy 1.0% of the set value or 20 msSuppression of harmonics DFT: -50 dB at f = n x fn, where n = 2, 3, 4, 5

Table 40. Transient/intermittent earth-fault protection (INTRPTEF) main settings

Parameter Function Value (Range) StepDirectional mode INTRPTEF 1=Non-directional

2=Forward3=Reverse

-

Operate delay time INTRPTEF 40...1200000 ms 10Voltage start value (voltage startvalue for transient EF)

INTRPTEF 0.01...0.50 x Un 0.01

Operation mode INTRPTEF 1=Intermittent EF2=Transient EF

-

Peak counter limit (Minrequirement for peak counterbefore start in IEF mode)

INTRPTEF 2...20 -

Min operate current INTRPTEF 0.01...1.00 x In 0.01


36 ABB

Table 41. Harmonics earth-fault protection (HAEFPTOC)


5% of the set value or 0.004 InStart time 1)2) Typically 77 msReset time Typically 40 msReset ratio Typically 0.96Operate time accuracy in definite time mode 1.0% of the set value or 20 msOperate time accuracy in IDMT mode 3) 5.0% of the set value or 20 msSuppression of harmonics -50 dB at f = fn

-3 dB at f = 13 fn1) Fundamental frequency current = 1.0 In. Harmonics current before fault = 0.0 In, harmonics fault current 2.0 Start value. Results based on statistical distribution of 1000

measurement.2) Includes the delay of the signal output contact3) Maximum Start value = 2.5 In, Start value multiples in range of 2...20

Table 42. HAEFPTOC main settings

Parameter Function Value (Range) StepStart value HAEFPTOC 0.05...5.00 In 0.01Time multiplier HAEFPTOC 0.05...15.00 0.01Operate delay time HAEFPTOC 100...200000 ms 10Minimum operate time HAEFPTOC 100...200000 ms 10Operating curve type HAEFPTOC Definite or inverse time

Curve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19

Table 43. Negative phase-sequence overcurrent protection (NSPTOC)


1.5% of the set value or 0.002 InStart time 1)2) Minimum Typical Maximum

IFault = 2 set Start valueIFault = 10 set Start value

23 ms15 ms

26 ms18 ms

28 ms20ms


Table 44. Negative phase-sequence overcurrent protection (NSPTOC) main settings

Parameter Function Value (Range) StepStart value NSPTOC 0.01...5.00 In 0.01Time multiplier NSPTOC 0.05...15.00 0.01Operate delay time NSPTOC 40...200000 ms 10Operating curve type1) NSPTOC Definite or inverse time

Curve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 191) For further reference, see Operation characteristics table

Table 45. Phase discontinuity protection (PDNSPTOC)


2% of the set valueStart time

Table 48. Residual overvoltage protection (ROVPTOV) main settings

Parameter Function Value (Range) StepStart value ROVPTOV 0.010...1.000 Un 0.001Operate delay time ROVPTOV 40...300000 ms 1

Table 49. Three phase undervoltage protection (PHPTUV)

Characteristic ValueOperation accuracy Depending on the frequency of the voltage measured: fn 2 Hz

1.5% of the set value or 0.002 UnStart time1)2) Minimum Typical Maximum

UFault = 0.9 set Start value 62 ms 66 ms 70 msReset time Typically 40 msReset ratio Depends on the set Relative hysteresisRetardation time

Table 51. Three-phase overvoltage protection (PHPTOV)



UFault = 1.1 set Start value 23 ms 27 ms 31 msReset time Typically 40 msReset ratio Depends of the set Relative hysteresisRetardation time

Table 54. Positive-sequence undervoltage protection (PSPTUV) main settings

Parameter Function Value (Range) StepStart value PSPTUV 0.010...1.200 Un 0.001Operate delay time PSPTUV 40...120000 ms 10Voltage block value PSPTUV 0.01...1.0 Un 0.01

Table 55. Negative-sequence overvoltage protection (NSPTOV)



UFault = 1.1 set Start valueUFault = 2.0 set Start value

33 ms24 ms

35 ms26 ms

37 ms28 ms

Reset time Typically 40 msReset ratio Typically 0.96Retardation time /f< 10 mHz

df/dt 100 mHz/s (in range |df/dt| < 5 Hz/s) 2.0% of the set value (in range 5 Hz/s < |df/dt| < 15 Hz/s)

Start time f>/f<

Table 58. Frequency protection (FRPFRQ) main settings

Parameter Function Value (Range) StepOperation mode FRPFRQ 1 = Freq3 = df/dt4 = Freq< + df/dt5 = Freq> + df/dt6 = Freq< OR df/dt7 = Freq> OR df/dt

Start value Freq> FRPFRQ 0.9000...1.2000 fn 0.0001Start value Freq< FRPFRQ 0.8000...1.1000 fn 0.0001Start value df/dt FRPFRQ -0.200...0.200 fn/s 0.005Operate Tm Freq FRPFRQ 80...200000 ms 10Operate Tm df/dt FRPFRQ 120...200000 ms 10

Table 59. Three-phase thermal overload protection for feeders (T1PTTR)


Current measurement: 1.5% of the set value or 0.002 In (atcurrents in the range of 0.01...4.00 In)

Operate time accuracy1) 2.0% of the theoretical value or 0.50 s1) Overload current > 1.2 Operate level temperature

Table 60. Three-phase thermal overload (T1PTTR) main settings

Parameter Function Value (Range) StepEnv temperature Set (Ambienttemperature used when theAmbSens is set to Off)

T1PTTR -50...100C 1

Current multiplier (Currentmultiplier when function is usedfor parallel lines)

T1PTTR 1...5 1

Current reference T1PTTR 0.05...4.00 In 0.01Temperature rise (Endtemperature rise above ambient)

T1PTTR 0.0...200.0C 0.1

Time constant (Time constant ofthe line in seconds)

T1PTTR 60...60000 s 1

Maximum temperature(temperature level for operate)

T1PTTR 20.0...200.0C 0.1

Alarm value (Temperature levelfor start (alarm)

T1PTTR 20.0...150.0C 0.1

Reclose temperature(Temperature for reset of blockreclose after operate)

T1PTTR 20.0...150.0C 0.1

Initial temperature (Temperatureraise above ambient temperatureat startup)

T1PTTR -50.0...100.0C 0.1


42 ABB

Table 61. Thermal overload protection, two time constants (T2PTTR)


Current measurement: 1.5% of the set value or 0.002 x In (atcurrents in the range of 0.01...4.00 x In)

Operate time accuracy1) 2.0% of the theoretical value or 0.50 s1) Overload current > 1.2 x Operate level temperature

Table 62. Thermal overload for protection, two time constants (T2PTTR) main settings

Parameter Function Value (Range) StepTemperature rise T2PTTR 0.0...200.0oC 0.1Max temperature T2PTTR 0.0...200.0oC 0.1Operate temperature T2PTTR 80.0...120.0 % 0.1Weighting factor p T2PTTR 0.00...1.00 0.01Short time constant T2PTTR 6...60000 s 1Current reference T2PTTR 0.05...4.00 x In 0.01Operation T2PTTR Off

On-

Table 63. Binary signal transfer (BSTGGIO)

Characteristic ValueSignalling delay Fiber optic link

Table 65. Circuit breaker failure protection (CCBRBRF) main settings

Parameter Function Value (Range) StepCurrent value (Operating phasecurrent)

CCBRBRF 0.05...1.00 In 0.05

Current value Res (Operatingresidual current)

CCBRBRF 0.05...1.00 In 0.05

CB failure mode (Operating modeof function)

CCBRBRF 1 = Current2 = Breaker status3 = Both

-

CB fail trip mode CCBRBRF 1 = Off2 = Without check3 = Current check

-

Retrip time CCBRBRF 0...60000 ms 10CB failure delay CCBRBRF 0...60000 ms 10CB fault delay CCBRBRF 0...60000 ms 10

Table 66. Three-phase inrush current detection (INRPHAR)

Characteristic ValueOperation accuracy At the frequency f = fn

Current measurement:1.5% of the set value or 0.002 InRatio I2f/I1f measurement:5.0% of the set value

Reset time +35 ms / -0 msReset ratio Typically 0.96Operate time accuracy +35 ms / -0 ms

Table 67. Three-phase inrush detection (INRPHAR) main settings

Parameter Function Value (Range) StepStart value (Ratio of the 2nd to the1st harmonic leading to restraint)

INRPHAR 5...100% 1

Operate delay time INRPHAR 20...60000 ms 1

Table 68. Multipurpose protection (MAPGAPC)

Characteristic ValueOperation accuracy 1.0% of the set value or 20 ms

Table 69. Multipurpose analog protection (MAPGAPC) main settings

Parameter Function Value (Range) StepStart value MAPGAPC -10000.0...10000.0 0.1Operate delay time MAPGAPC 0...200000 ms 100Operation mode MAPGAPC Over

Under-


44 ABB

Table 70. Fault locator function (SCEFRFLO)

Characteristic ValueMeasurement accuracy At the frequency f = fn

Impedance:2.5% or 0.25 Distance:2.5% or 0.16 km/0.1 mileXC0F_CALC:2.5% or 50 IFLT_PER_ILD:5% or 0.05

Table 71. Fault locator (SCEFRFLO) main settings

Parameter Function Value (Range) StepZ Max phase load SCEFRFLO 1.0...10000.00 0.1Ph leakage Ris SCEFRFLO 20...1000000 1Ph capacitive React SCEFRFLO 10...1000000 1R1 line section A SCEFRFLO 0.000...1000.000 /pu 0.001X1 line section A SCEFRFLO 0.000...1000.000 /pu 0.001R0 line section A SCEFRFLO 0.000...1000.000 /pu 0.001X0 line section A SCEFRFLO 0.000...1000.000 /pu 0.001Line Len section A SCEFRFLO 0.000...1000.000 pu 0.001

Table 72. Line differential protection (LNPLDF)

Characteristics ValueOperation accuracy 1) Depending on the frequency of the measured current: fn 2 Hz

Low stage 2.5% of the set valueHigh stage 2.5% of the set value

Minimum Typical MaximumHigh stage, operate time 2)3) 22 ms 25 ms 29 msReset time Typically 40 msReset ratio Typically 0.96Retardation time (Low stage)

Table 73. Line differential protection (LNPLDF) main settings

Parameter Values (Range) Unit DescriptionHigh operate value 200...4000 % In Instantaneous stage operate valueLow operate value 10...200 % In Basic setting for the stabilized stage startOperate delay time 45...200000 ms Operate delay time for stabilized stageOperate curve type 1=ANSI Ext. inv.

3=ANSI Norm. inv.5=ANSI Def. Time9=IEC Norm. inv.10=IEC Very inv.12=IEC Ext. inv.15=IEC Def. Time

Selection of time delay curve for stabilizedstage

Time multiplier 0.05...15.00 Time multiplier in IDMT curvesStart value 2.H 10...50 % The ratio of the 2. harmonic component to

fundamental component required for blockingCT ratio correction 0.200...5.000 Remote phase current transformer ratio

correction

Table 74. High impedance fault detection (PHIZ) main settings

Parameter Function Value (Range) StepSecurity Level PHIZ 1...10 1System type PHIZ 1=Grounded

2=Ungrounded

Line Differential Protection and Control 1MRS756500 HRED6

Documents

Product Guide - RED615