siprotec catalog 2008 en

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SIPROTEC

Numerical Protection Relays

Protection Systems

Catalog SIP 2008

Editorial

SIPROTEC more than just protection

This edition of the SIPROTEC catalog incorporates many suggestionsfrom our readers, along with information about innovations andsupplementary products.

In the field of power distribution and consumption, SIEMENS nowoffers a new family of SIPROTEC Compact devices. The 7SJ80 lineprotection relay offers a vast amount of functionality in a compacthousing at an affordable price. The functional packages of 7SK80 areespecially designed for protection and management of asynchronousmotors of all sizes. Of course, the family has full native IEC 61850capability besides supporting all other major communication proto-cols, for seamless integration into all kinds of system environments.

This is exactly what you would expect because SIPROTEC stands forinnovation, reliability and integration into protection and control.

Another new family member is the web-based Power Quality moni-toring and analysis suite, SIMEAS SAFIR. From now on, you will beable to effectively analyze network disturbances and take correctiveaction in a matter of minutes, no matter where you are. Take a fewminutes to work through the SIMEAS SAFIR tutorial and you will bedelighted by the benefits of the product.

IEC 61850 has become established as the communication backbonefor the new era of energy automation and control, and SIPROTEC isits highlight. We are happy to share with you all the references andexperience we have gathered in recent years.

For your convenience, this SIPROTEC catalog is also available on CDROM. For further information on SIPROTEC applications and fea-tures, our local Siemens representative will assist you, but dont missthe interactive multimedia DVD SIPROTEC Tutorial, which willguide you through many of these features.

To receive this media free of charge, just ask your local Siemens repre-sentative or send us an e-mail ([email protected]).

We compiled this catalog with your needs in mind and hope it willassist you to optimally and conveniently select from among the avail-able features and products.

We wish you a pleasant and productive experience with SIPROTEC.

Paulo Ricardo StarkVice PresidentEnergy Distribution Energy AutomationProtection and Power Quality Systems DivisionEnsuring reliable energy supply.

Contents

Product Selection 1

Overview/Applications 2

Operating Programs 3

Communication 4

Overcurrent Protection 5

Distance Protection 6

Line Differential Protection 7

Transformer Differential Protection 8

Busbar Differential Protection 9

Relays for Various Protection Applications 10

Generator Protection 11

Motor Protection 12

Power Quality 13

Substation Automation 14

Relay Communication Equipment 15

Test Equipment and Accessories 16

Appendix 17

SIPROTECNumerical Protection Relays

Catalog SIP 2008

Siemens AG 2008

Supersedes Catalog SIP 2006

2 Siemens SIP 2008

Product IndexType Description Page

DIGSI 4 Operating software for SIPROTEC devices 3/7

OSCOP P Operating software for power quality 13/67

SICAM PAS Substation automation system 14/3

SIGRA 4 Evaluation software for fault records 3/12

SIMEAS P Power meter 13/3

SIMEAS Q Power quality recorder 13/31

SIMEAS R Disturbance recorder and PQ monitoring unit 13/41

SIMEAS T Digital transducer 13/19

SIMEAS SAFIR Analysis and monitoring software for power quality 13/79

3RV1 Voltage transformer mini circuit-breaker 16/17

6MD61 IO-box 14/11

6MD63 Bay control unit 14/19

6MD66 High-voltage bay control unit 14/21

6MD9 Substation automation system 14/3

7PA22/23 Auxiliary relay 16/5

7PA26/27 Auxiliary relay 16/9

7PA30 Trip circuit supervision 16/12

7RW6 Voltage, frequency and overexcitation relay 11/71

7SA522 Distance protection relay for transmission lines 6/45

7SA6 Distance protection relay for all voltage levels 6/3

7SD5 Multi-end differential protection relay 7/43

7SD60 Pilot-wire current differential protection relay 7/3

7SD61 Differential protection relay for 2 line ends 7/17

7SJ45 easy Overcurrent protection relay powered by CT 5/3

7SJ46 easy Overcurrent protection relay 5/11

7SJ600 Overcurrent, motor and overload protection relay 5/19

7SJ602 Overcurrent, motor and overload protection relay 5/31

7SJ80 Multifunction protection relay 5/55




7SJ64 Multifunction protection relay with synchronization 5/183

7SK80 Motor protection relay 12/9

7SN60 Transient earth-fault protection relay 10/31

7SS52 Distributed busbar and breaker failure protection 9/19

7SS60 Centralized busbar protection 9/3

7SV6 Numerical circuit-breaker failure protection relay 10/21

Siemens SIP 2008 3

Product IndexType Description Page

7TS 16 Annunciation relay 16/13

7UM61 Multifunction generator and motor protection relay 11/3

7UM62 Multifunction generator, motor and transformer protection relay 11/33

7UT6 Differential protection relay for transformers, generators, motors and busbars 8/3

7UW5 Tripping matrix 11/69

7VE6 Multifunction paralleling device 11/81

7VK6 Breaker management relay 10/3

7XV5101 RS232 FO connector modules 15/3

7XV5103 RS485 Bus system 15/5

7XV5104 Bus cables for time synchronization 15/13

7XV5105 Bus cables for time synchronization for 7SD5 15/15

7XV5300 Star coupler 15/17

7XV5450 Mini star-coupler 15/19

7XV5461 Two-channel serial optical repeater for mono-mode FO cable 15/23

7XV5461 Two-channel serial optical repeater for 1 mono-mode FO cable 15/27

7XV5461 Two-channel serial optical repeater for multi-mode FO cables 15/31

7XV5550 Active mini star-coupler 15/35

7XV5650/5651 RS485 FO converter 15/39

7XV5652 RS232 FO converter 15/43

7XV5653 Two-channel binary transducer 15/47

7XV5654 GPS/DCF77 Time synchronization unit 15/67

7XV5655 Ethernet modem 15/69

7XV5655 Ethernet serial hub for substations 15/73

7XV5662 Communication converter for X.21/RS422 and G.703.1 15/51

7XV5662 Communication converter for pilot wires 15/55

7XV5662 Two-channel serial communication converter 15/59

7XV5662 Temperature monitoring box 15/63

7XV5664 GPS/DCF77 Time signal receiver 15/67

7XV57 RS232 RS485 converter 15/77

7XV5710 USB RS485 converter cable 15/81

7XV5820 Industrial modem and modem-router with switch 15/85

7XV5850/51 Ethernet modems for office applications 15/95

7XV75 Test switch 16/3

4 Siemens SIP 2008

1Product Selection PageRelay Functions 1/2

1 Product Selection

1

Siemens SIP 2008

Relay Functions

1/21/2

Dis

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Mo

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Protection functions Type 7SA

522

7SA

6

7SD

600

7SD

57S

D61

0

7SJ4

57S

J46

7SJ6

007S

J602

7SJ8

07S

J61

7SJ6

27S

J63

7SJ6

47S

K80

7VH

607U

T612

7UT6

137U

T63

7SS6

07S

S52

ANSI No.* Description

14 Locked rotor protection

21 Distance protection, phase

21N Distance protection, earth (ground)

21FL Fault locator

24 Overfluxing (V/f protection)

25 Synchronizing, synchronism check

27 Undervoltage

27/34 Stator earth-fault 3rd harmonic

32 Directional power

32F Forward power

32R Reverse power

37 Undercurrent or underpower

40 Loss of field

46 Load unbalance, negative phase-sequence overcurrent

47 Phase-sequence voltage

48 Motor starting protection

49 Thermal overload

49R Rotor thermal protection

49S Stator thermal protection

50 Instantaneous overcurrent

50N Instantaneous earth-faultovercurrent

50BF Breaker failure

51GN Zero speed and underspeed device

51 Overcurrent-time relay, phase

51N Overcurrent-time relay, earth

51M Load jam protection

51V Overcurrent-time relay,voltage controlled

59 Overvoltage

59N Residual voltage earth-faultprotection

59GN Stator earth-fault protection

64 100 % Stator earth-fault protection(20 Hz)

64R Rotor earth fault

Standard function Option

* ANSI/EEE C 37.2: IEEE Standard Electrical Power System Device Function Numbers

1 Product Selection

1

Siemens SIP 2008 1/31/3

Gen

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Syn

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freq

uen

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Protection functions Type 7U

M61

7UM

62

7VK

617V

E6

7SV

600

7RW

600


14 Locked rotor protection

21 Distance protection, phase

21N Distance protection, earth

21FL Fault locator

24 Overfluxing (V/f protection)

25 Synchronizing, synchronism check

27 Undervoltage

27/34 Stator earth-fault 3rd harmonic

32 Directional power

32F Forward power

32R Reverse power

37 Undercurrent or underpower

40 Loss of field

46 Load unbalance, negative phase-sequence overcurrent

47 Phase-sequence voltage

48 Incomplete sequence, locked rotor

49 Thermal overload

49R Rotor thermal protection

49S Stator thermal protection

50 Instantaneous overcurrent

50N Instantaneous earth-faultovercurrent

50BF Breaker failure

51GN Zero speed and underspeed dev.

51 Overcurrent-time relay, phase

51N Overcurrent-time relay, earth

51M Load jam protection

51V Overcurrent-time relay,voltage controlled

59 Overvoltage

59N Residual voltage earth-fault protection

59GN Stator earth-fault protection

64 100 % Stator earth-fault protection(20 Hz)

64R Rotor earth fault



1 Product Selection

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Siemens SIP 2008

Relay Functions

1/4

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Protection functions Type 7SA

522

7SA

6

7SD

600

7SD

5

7SD

610

7SJ4

5

7SJ4

6

7SJ6

00

7SJ6

02

7SJ8

0

7SJ6

1

7SJ6

2

7SJ6

3

7SJ6

4

7SK

80

7VH

60

7UT6

12

7UT6

13

7UT6

3

7SS6

0

7SS5

2


67 Directional overcurrent

67N Directional earth-fault overcurrent 1)

67G Stator earth-faultdirectional overcurrent

68 Power swing detection

74TC Trip circuit supervision

78 Out-of-step protection

79 Auto-reclosure

81 Frequency protection

81R Rate-of-frequency-change protection

Vector jump supervision

85 Carrier interface/remote trip

86 Lockout function

87G Differential protection generator

87T Differential protection transformer

87BB Differential protection busbar

87M Differential protection motor

87L Differential protection line

87N Restricted earth-fault protection



1) only sensitive directional earth-fault overcurrent (67Ns)

1 Product Selection

1

Siemens SIP 2008 1/5

Gen

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Syn

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Protection functions Type 7U

M61

7UM

62

7VK

617V

E6

7SV

600

7RW

600


67 Directional overcurrent

67N Directional earth-fault overcurrent

67G Stator earth-faultdirectional overcurrent

68 Power swing detection

74TC Trip circuit supervision

78 Out-of-step protection

79 Auto-reclosure

81 Frequency protection

81R Rate-of-frequency-change protection

Vector jump supervision

85 Carrier interface/remote trip

86 Lockout function

87G Differential protection generator

87T Differential protection transformer

87BB Differential protection busbar

87M Differential protection motor

87L Differential protection line

87N Restricted earth-fault protection



1Siemens SIP 20081/6

Overview/Applications PageRelay Families 2/4

Typical Protection Schemes 2/20

Protection Coordination 2/44 2

Siemens SIP 2008

2

2/2

Siemens SIP 2008

2 Overview

2

2/3

Overview

Relay FamiliesIntroduction 2/ 4

SIPROTEC easy 2/ 9

SIPROTEC 4 relays 2/10

SIPROTEC Compact (80 relays) 2/17

SIPROTEC 600 relays 2/19

Typical ProtectionSchemesCables and overhead lines 2/22

Transformers 2/32

Motors 2/35

Generators 2/37

Busbars 2/40

Networks 2/42

ProtectionCoordinationTypical applications and functions 2/44

Verification of design 2/50

Instrument transformers 2/52

Description

Simplicity in a complex worldQuite simply SIPROTEC 4

Face the future with confidence andinnovative solutions.

SIPROTEC 4 is a flexible and powerfulsolution for protecting your power sys-tem.

Ergonomic key path and graphic displayensure reliable operation. The powerfulsoftware tool DIGSI 4 assists theengineer in comprehensive relay man-agement and fault analysis. Only onetool is required for all SIPROTEC relays.

SIPROTEC 4 offers much more:

Function mix of protection, control andmeasurement

Choice of open communicationstandards like IEC 61850 andIEC 60870-5-103 protocols, DNP 3,MODBUS and PROFIBUS

Communication modules also forretrofitting and upgrading to IEC 61850communication standard

Siemens actively supported internationalstandard IEC 61850 and is the first man-ufacturer to offer protection relays andsubstation control systems with anIEC 61850-compliant communicationprotocol.

By the end of 2007, approx. 30,000SIPROTEC devices in more than300 substations are implemented inaccordance with the IEC 61850 com-munication standard.

A flexibility that is a pleasure to use.As pioneers in numerical protection andsubstation communication, we inviteyou to take advantage of SIPROTEC 4.

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2 Overview

Relay Families

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Introduction

Siemens is one of the worlds leading suppliers ofprotection equipment for power systems.

Thousands of our relays ensure first-classperformance in transmission and distributionnetworks on all voltage levels, all over the world,in countries of tropical heat or arctic frost.

For many years, Siemens has also significantlyinfluenced the development of protectiontechnology.

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SIPROTEC 4 family

SIPROTEC easy series

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In 1976, the first minicomputer (process com-puter)-based protection system was commis-sioned: A total of 10 systems for 110/20 kV sub-stations was supplied and is still operatingsatisfactorily today.

Since 1985, we have been the first to manufacturea range of fully numerical relays with standardizedcommunication interfaces.Today, Siemens offers a complete range of protec-tion relays for all applications including numericalbusbar and machine protection.To date, more than 600,000 numerical protectionrelays from Siemens are providing successful ser-vice, as stand-alone units in traditional systems oras components of combined substation protectionand substation control.Meanwhile, the SIPROTEC 4 series has establisheditself right across the market, incorporating manyyears of operational experience with thousands ofrelays, together with users requirements.

State-of-the-art technology

Mechanical and solid-state (static) relays havebeen almost completely phased out of ourproduction because numerical relays are nowpreferred by the users due to their decisiveadvantages:

Compact design and lower costs due to integrationof many functions into one relay

High availability even with less maintenance dueto integral self-monitoring

No drift (aging) of measuring characteristics dueto fully numerical processing

High measuring accuracy due to digital filteringand optimized measuring algorithms

Many integrated add-on functions, for example,for load-monitoring, event/fault recording andthermal monitoring

Local operation keypad and display designed tomodern ergonomic criteria

Easy and reliable read-out of information via serialinterfaces with a PC, locally or remotely withDIGSI (one tool for all relays)

Possibility to communicate with higher-levelcontrol systems using standardized protocolsaccording to IEC 61850 via Ethernet com-munication

SIPROTEC Compact (80 series)

SIPROTEC 600series

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2 Overview

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Fig. 2/2Numerical relays offerincreased informationavailability

Modern protection management

All the functions, for example, of a line protectionscheme can be incorporated in one unit:

Distance protection with associated add-on andmonitoring functions

Universal teleprotection interface by binary in-put/contacts or serial interface

Auto-reclosure and synchronism check

Protection-related information can be called upon-line or off-line, such as:

Distance to fault

Fault currents and fault voltages

Relay operation data (fault detector pickup, oper-ating times etc.)

Set values

Line load data (kV, A, MW, kVAr)

To fulfill vital protection redundancy require-ments, only those functions which are interde-pendent and directly associated with each otherare integrated in the same unit. For back-up pro-tection, one or more additional units should beprovided.

All relays can stand fully alone. Thus, the tradi-tional protection concept of separate main andbackup protection as well as the external connec-tion to the switchyard remain unchanged.

One feeder, one relay concept

Analog protection schemes have been engineeredand assembled from individual relays. Interwiringbetween these relays and scheme testing has beencarried out manually in the workshop.

Data sharing now allows for the integration ofseveral protection and protection-related tasksinto one single numerical relay. Only a few exter-nal devices may be required for completion of thetotal scheme. This has significantly lowered thecosts of engineering, assembly, panel wiring, test-ing and commissioning. Scheme failure probabil-ity has also been lowered.

Engineering has moved from schematic diagramstowards a parameter definition procedure. A pow-erful user-definable logic integrated in SIPROTEC 4allows flexible customized design for protection,control and measurement.

Measuring included

For many applications, the accuracy of the protec-tion current transformer is sufficient for opera-tional measuring. The additional measuring c.t.was required to protect the measuring instru-ments under short-circuit conditions. Due to thelow thermal withstand capability of the measuringinstruments, they could not be connected to theprotection c.t.. Consequently, additional measur-ing core c.t.s and measuring instruments are nowonly necessary where high accuracy is required,e.g. for revenue metering.

2 Overview

Relay Families

Siemens SIP 2008

2

2/6

Fig. 2/3PC-aided settingprocedure

Fig. 2/4 Communication options

On-line remote data exchange

A powerful serial data link provides for interroga-tion of digitized measured values and other infor-mation stored in the protection units, for printoutand further processing at the substation or systemcontrol level.In the opposite direction, setting groups may bealtered or test routines initiated from a remotecontrol center.

For greater distances, especially in outdoorswitchyards, fiber-optic cables are preferably used.This technique has the advantage that it is totallyunaffected by electromagnetic interference.

Off-line dialog with numerical relays

A simple built-in operator panel which requiresno special software knowledge or codeword tablesis used for parameter input and readout.

This allows operator dialog with the protectionrelay. Answers appear largely in plain-text on thedisplay of the operator panel. The dialog is dividedinto three main phases:

Input, alternation and readout of settings

Testing the functions of the protection unit and

Readout of relay operation datafor the last system faults.

Modern power system protection management

A notebook PC may be used for upgraded protec-tion management.

The MS Windows-compatible relay operationprogram DIGSI is available for entering and read-out of setpoints and archiving of protection datafor all SIPROTEC relays. For the whole relay fam-ily only one PC-software is required. Relay up-dates are offered now on Internet athttp://www.siprotec.com.

Siemens SIP 2008

2 Overview

2

2/7

Fig. 2/5System-wide setting and relay operation library

Fig. 2/6Alternate parameter groups

Setpoints Relay operationsThe relays may be set in 2 steps. First, all relaysettings are prepared in the office with the aid of alocal PC and stored on a file. On site, the settingscan then be downloaded from a PC into the relay.The relay confirms the settings and thus providesan unquestionable record.

Vice versa, after a system fault, the relay memorycan be uploaded to a PC, and comprehensive faultanalysis can then take place in the engineers officeif required.

Alternatively, the total relay dialog can be guidedfrom any remote location via a modem-telephoneconnection (Fig. 2/4) or via the utility network.

Relay data management

Distribution type relays have some important20-30 setpoints. If we consider a power systemwith about 500 relays, then the number adds up to10,000 settings. This requires considerable expen-diture in setting the relays and filing retrievalsetpoints.

A personal computer-aided human-machine dia-log and archiving program, e.g. DIGSI, assists therelay engineer in data filing and retrieval.

Corrective rather than preventive maintenance

Numerical relays monitor their own hardware andsoftware. Exhaustive self-monitoring and failurediagnostic routines are not restricted to the pro-tection relay itself, but are methodically carriedthrough from current transformer circuits totripping relay coils.

Equipment failures and faults in the c.t. circuitsare immediately reported and the protection relayis blocked.

Thus, the service personnel is now able to correctthe failure upon occurrence, resulting in a signifi-cantly upgraded availability of the protection sys-tem.

Adaptive relaying

Numerical relays now offer reliable, convenientand comprehensive matching to changing condi-tions. Matching may be initiated either by therelays own intelligence or from other systems viacontacts or serial telegrams. Modern numericalrelays contain a number of parameter sets that canbe pretested during commissioning of the scheme(Fig. 2/6). One set is normally operative.Transfer to the other sets can be controlled viabinary inputs or serial data link.

There is a number of applications for which mul-tiple setting groups can upgrade the scheme per-formance, e.g.

For use as a voltage-dependent control ofovercurrent-time relay pickup values to overcomealternator fault current decrement to belownormal load current when the automatic voltageregulator (AVR) is not in automatic operation.

For maintaining short operation times with lowerfault currents, e.g. automatic change of settings ifone supply transformer is taken out of service.

For switch-onto-fault protection to provideshorter time settings when energizing a circuitafter maintenance. The normal settings can berestored automatically after a time delay.

For auto-reclosure programs, i.e. instantaneousoperation for first trip and delayed operation afterunsuccessful reclosure.

For cold load pickup problems where high startingcurrents may cause relay operation.

For ring open or ring closed operation.

2 Overview

Relay Families

Siemens SIP 2008

2

2/8

Implemented functions

SIPROTEC relays are available with a variety ofprotective functions. See description of the relayfamilies (page 2/9 and following).

Fig. 2/7 leftSwitchgear withnumerical relay (7SJ62)and traditional control

Fig. 2/7 rightSwitchgear withcombined protectionand control relay (7SJ64)

Fig. 2/8SIPROTEC 4 relays7SJ61/62/63, 64implemented functions

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1)RTD = resistance temperature detector 2) VT connection for 7SJ62/63/64 only

The high processing power of modern numericalunits allows further integration of non-protectiveadd-on functions.

The question as to whether separate or combinedrelays should be used for protection and controlcannot be uniformly answered. In transmission-type substations, separation into independenthardware units is still preferred, whereas on the

distribution level a trend towards higher functionintegration can be observed. Here, combinedfeeder/line relays for protection, monitoring andcontrol are on the march (Fig. 2/7).

Relays with protection functions only and relayswith combined protection and control functionsare being offered. SIPROTEC 4 relays offercombined protection and control functions.SIPROTEC 4 relays support the one relay onefeeder concept and thus contribute to a consider-able reduction in space and wiring.

With the well-proven SIPROTEC 4 family, Siemenssupports both stand-alone and combined solu-tions on the basis of a single hardware and soft-ware platform. The user can decide within widelimits on the configuration of the control and pro-tection functions in the line, without influencingthe reliability of the protection functions (Fig. 2/8).

The following solutions are available within onerelay family:

Separate control and protection relays

Feeder protection and remote control of the linecircuit-breaker via the serial communication link

Combined relays for protection, monitoring andcontrol

Mixed use of the different relay types is possibleon account of the uniform operation and commu-nication procedures.

Siemens SIP 2008

2 Overview

2

2/9

Fig. 2/9DIGSI 4, one operat-ing tool for allSIPROTEC devices

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Siemens offers the user a uniform technique cov-ering the whole range of protection applications.This includes a uniform operator concept, uni-form housing technology, common communica-tion protocols and a uniform technology.

This offers a number of advantages for the user:

Reduced engineering and testing efforts due towell-suited functions

Reduced training due to uniform operation andsetting for all relays

Uniform data management due to a commonoperator program

Our 3 product families have a common basis andwith their characteristic features are optimized foryour main area of application.

The SIPROTEC 4 family:

A great variety of units ranging from overcurrent-time protection for medium-voltage applicationsto distance and differential protection for extra-high-voltage applications. All the units have con-trol functions (partly with graphic display) and of-fer a great variety of communications possibilities.They have a large number of integrated protectionfunctions, from which the user can easily selectthose required for his specific case of application.

The SIPROTEC Compact ('80 series):

Advanced functionality at minimum space. TheSIPROTEC Compact relays provide a functionalityalmost equal to SIPROTEC 4, however in a compactsize. High adaptability will be achieved throughpluggable current and voltage terminal blocks andexchangeable communication modules. A quickdata acquisition is possible through USB front port.

The SIPROTEC '600 series:

Cost-effective units especially for use in industry orpower supply utilities, where the entire scope offunctions of the SIPROTEC 4 family is not required.

The SIPROTEC easy series:

For simple applications, the relay seriesSIPROTEC easy completes the SIPROTEC family.

SIPROTEC easy means:

High quality at a favorable price

Simple setting via dip switches, no PC programrequired

Easy mounting due to compact housing

Current transformer (CT) powered or auxiliaryvoltage supplied version available

Condensation-proof version available

2 Overview

Relay Families

Siemens SIP 2008

2

2/10

SIPROTEC 4 relays

SIPROTEC 4 relays are available in 1/3 to 1/1of 19 wide housings with a standard height of243 mm. Their size is compatible with that ofother relay families. Therefore, compatible ex-change is always possible.All wires (cables) are connected at the rear side ofthe relay with or without ring cable lugs. A specialrelay version with a detached cable-connected op-erator panel (Fig. 2/13) is also available. It allows,for example, the installation of the relay itself inthe low-voltage compartment and of the operatorpanel separately in the door of the switchgear.

TerminalsStandard relay version with screw-type terminals

Current terminals

Connection Wmax = 12 mm

Ring cable lugs d1 = 5 mm

Wire size 2.7 - 4 mm2 (AWG 13 - 11)

Direct Solid conductor,connection flexible lead, connector sleeve

Wire size 2.7 - 4 mm2 (AWG 13 - 11)

Voltage terminals

Connection Wmax = 10 mm

Ring cable lugs d1 = 4 mm

Wire size 1.0 - 2.6 mm2 (AWG 17 - 13)

Direct connection Solid conductor, flexiblelead, connector sleeve

Wire size 0.5 - 2.5 mm2 (AWG 20 - 13)

Some relays are alternatively availablewith plug-in voltage terminals

Current terminalsScrew type (see standard version)

Voltage terminals

2-pin or 3-pinconnectors

Wire size 0.5 - 1.0 mm2

0.75 - 1.5 mm2

1.0 - 2.5 mm2

Fig. 2/10 1/1 of 19

Fig. 2/11 1/2 of 19

Fig. 2/13SIPROTEC 4

combined protection,control and

monitoring relay 7SJ63with detached operator

panel

Fig. 2/12 1/3 of 19

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Adaptation to substation environment

Not only can the software of SIPROTEC units beflexibly adapted to substation conditions; theunits themselves can be adapted to the secondaryCT rated current IN (1 A or 5 A) or the auxiliaryvoltage Vaux via internal settable jumpers. Toachieve a correct indication of the secondary mea-sured values on the display of the relay, you haveto reset the CT rated current parameter inDIGSI. You should also mark the modificationsyou have made on the Modification note plate(Fig. 2/14).

Siemens SIP 2008

2 Overview

2

2/11

Fig. 2/15

Freely assignable LEDs are used to display processor device information. The LEDs can be labelledaccording to user requirements. An LED reset keyresets the LEDs and can be used for LED testing.

On the backlit LCD display, process and deviceinformation can be displayed as text.

4 configurable function keys permit the user toexecute frequently used actions simply and fast.

RS232 operator interface (for DIGSI)

Numerical keys

Keys for navigation

Process and relay information can be displayed onthe large illuminated LC display either graphicallyin the form of a mimic diagram or as text in vari-ous lists.

The keys mainly used for control of theswitchgear are located on the control axisdirectly below the display.

Two key-operated switches ensure rapidand reliable changeover between Local andRemote control and between interlockedand non-interlocked operation.

Fig. 2/16

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Local operation

All operator actions can be executed and informa-tion displayed via an integrated user interface.Two alternatives for this interface are available.

Additional features of the interface withgraphic display.

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SIPROTEC 4 relays

Apart from the relay-specific protection functions,the SIPROTEC 4 units have a multitude of addi-tional functions which

Provide you with information for the evaluationof faults

Facilitate adaption to your specific application

Facilitate monitoring and control of your installa-tion

Operational measured values

The large scope of measured and limit values per-mits improved power system management as wellas simplified commissioning.

The r.m.s. values are calculated from the acquiredcurrent and voltage along with the power factor,frequency, active and reactive power. The follow-ing functions are available depending on the relaytype

Currents IL1, IL2, IL3, IN, IEE (67Ns)

Voltages VL1, VL2, VL3, VL1-L2, VL2-L3, VL3-L1

Symmetrical components I1, I2, 3I0; V1, V2, 3V0

Power Watts, Vars, VA/P, Q, S

Power factor p.f. (cos )

Frequency

Fig. 2/17Operational measuredvalues on the displayof the device

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Fig. 2/18Fault event log onthe graphic displayof the device LS

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Energy kWh kVarh, forward and reversepower flow

Mean as well as minimum and maximum currentand voltage values

Operating hours counter

Mean operating temperature of overload function

Limit value monitoringLimit values are monitored using programmablelogic in the CFC. Commands can be derived fromthis limit value indication.

Zero suppressionIn a certain range of very low measured values, thevalue is set to zero to suppress interference.

Metered values (some types)

For internal metering, the unit can calculateenergy metered values from the measured cur-rent and voltage values. If an external meterwith a metering pulse output is available, someSIPROTEC 4 types can obtain and process meter-ing pulses via an indication input.

The metered values can be displayed and passedon to a control center as an accumulation withreset. A distinction is made between forward,reverse, active and reactive energy.

Measuring transducer (some types)

Knee characteristicFor measuring transducers it sometimes makessense to extend a small range of the input value,e.g. for the frequency that is only relevant in therange 45 to 55, 55 to 65 Hz. This can be achievedby using a knee characteristic.

Live-zero monitoring4 - 20 mA circuits are monitored for open-circuitdetection.

Operational indications and fault indicationswith time stamp

The SIPROTEC 4 units provide extensive data forfault analysis as well as control. All indicationslisted below are stored even if the power supply isdisconnected.

Fault event logThe last eight network faults are stored in the unit.All fault recordings are time-stamped with a reso-lution of 1 ms.

Operational indicationsAll indications that are not directly associated witha fault (e.g. operating or switching actions) arestored in the status indication buffer. The timeresolution is 1 ms.

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Fig. 2/19Display and evaluationof a fault record usingSIGRA

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Display editor

A display editor is available to design the displayon SIPROTEC 4 units with graphic display. Thepredefined symbol sets can be expanded to suitthe user. The drawing of a single-line diagram isextremely simple. Load monitoring values (analogvalues) and any texts or symbols can be placed onthe display where required.

Four predefined setting groups for adapting relaysettings

The settings of the relays can be adapted quicklyto suit changing network configurations. Therelays include 4 setting groups which can be pre-defined during commissioning or even changedfrom remote via a DIGSI 4 modem link. The set-ting groups can be activated via binary inputs, viaDIGSI 4 (local or remote), via the integrated key-pad or via the serial substation control interface.

Fault recording up to 5 or more seconds

The sampled values for phase currents, earth(ground) currents, line and zero-sequence cur-rents are recorded in a fault record. The recordcan be started using a binary input, on pickup orwhen a trip command occurs. Up to eight faultrecordings may be stored. For test purposes, it ispossible to start a fault recording via DIGSI 4. Ifthe storage capacity is exceeded, the oldest faultrecording in each case is overwritten.

For protection functions with long delay times ingenerator protection the r.m.s. value recording isavailable. Storage of relevant calculated variables(V1, VE, I1, I2, IEE, P, Q, f-fn) takes place at incre-ments of one cycle. The total time is 80 seconds.

Time synchronization

A battery-backed clock is a standard componentand can be synchronized via a synchronizationsignal (DCF77, IRIG B via satellite receiver),binary input, system interface or SCADA(e.g. SICAM). A date and time is assigned toevery indication.

Selectable binary inputs and outputs

Binary inputs, outputs and LEDs can be assignedto perform specific functions as defined by theuser.

Selectable function keys

Four function keys can be assigned to permit theuser to perform frequently recurring actions veryquickly and simply.

Typical applications are, for example to displaythe list of operating indications or to performautomatic functions, such as Switching ofcircuit-breaker.

Continuous self-monitoring

The hardware and software are continuouslymonitored. If abnormal conditions are detected,the unit signals immediately. In this way, a greatdegree of safety, reliability and availability isachieved.

Reliable battery monitoring

The battery that is provided is used to backup theclock, the switching statistics, the status and faultindications and the fault recording in the event ofa power supply failure. Its function is checked bythe processor at regular intervals. If the capacityof the battery is found to be declining, an alarm isgenerated. Regular replacement is therefore notnecessary.

All setting parameters are stored in theFlash-EPROM and are not lost if the power supplyor battery fails. The SIPROTEC 4 unitremains fully functional.

Commissioning support

Special attention has been paid to commissioning.All binary inputs and output contacts can be dis-played and activated directly. This can signifi-cantly simplify the wiring check for the user.Test telegrams to a substation control system canbe initiated by the user as well.

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Fig. 2/20CFC logic with module library

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SIPROTEC 4 relays

CFC: Programming logic

With the help of the CFC graphic tool (Continu-ous Function Chart) interlocking schemes andswitching sequences can be configured simply viadrag and drop of logic symbols; no special knowl-edge of programming is required. Logical ele-ments, such as AND, OR, flip-flops and timerelements are available. The user can also generateuser-defined annunciations and logical combina-tions of internal or external signals.

Communication interfaces

With respect to communication, particular em-phasis has been placed on high levels of flexibility,data integrity and utilization of standards com-mon in energy automation. The design of thecommunication modules permits interchange-ability on the one hand, and on the other handprovides openness for future standards.

Local PC interface

The PC interface accessible from the front of theunit permits quick access to all parameters andfault event data. Of particular advantage is the useof the DlGSl 4 operating program during commis-sioning.Fig. 2/21 Protection relay

Fig. 2/22Communication module,optical

Fig. 2/23Communication moduleRS232, RS485

Fig. 2/24Communication module,optical, double-ring

Fig. 2/25Rear view with wiring,terminal safety cover andserial interface

Retrofitting: communication modules

It is possible that the relays are supplied directlywith two communication modules for the serviceand substation control interfaces or to retrofit thecommunication modules at a later stage. Themodules are mounted on the rear side of the relay.As standard, the time synchronization interface isalways supplied.The communication modules are available for theentire SIPROTEC 4 relay range. Depending on therelay type the following protocols are available:IEC 60870-5-103, PROFIBUS-FMS/DP, MODBUSRTU, DNP 3.0, Ethernet with IEC 61850 (forsome relays). No external protocol converter is re-quired.

The following interfaces can be applied for:

Service interface (optional)Several protection relays can be centrally operatedwith DIGSI 4, e.g. via a star coupler or RS485 bus.On connection of a modem, remote control ispossible. This provides advantages in fault clear-ance, in particular in unmanned power stations.(Alternatively, the external temperature monitor-ing box can be connected to this interface.)

System interface (optional)This is used to carry out communication with acontrol system and supports, depending on themodule connected, a variety of communicationprotocols and interface designs.

Time synchronization interfaceA synchronization signal (DCF 77, IRIG B via sat-ellite receiver) may be connected to this input, ifno time synchronization is executed on the systeminterface. This offers a high-precision time tagging.

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With respect to communication, particular em-phasis is placed on the requirements in energyautomation:

Every data item is time-stamped at the source, i.e.where it originates.

The communication system automatically handlesthe transfer of large data blocks (e.g. fault record-ings or parameter data files). The user can applythese features without any additional program-ming effort.

For reliable execution of a command, the relevantsignal is first acknowledged in the unit involved.When the command has been enabled and exe-cuted, a check-back indication is issued. The actualconditions are checked at every command han-dling step. Whenever they are not satisfactory,controlled interruption is possible.

Safe bus architecture

Fiber-optic double ring circuit via EthernetThe fiber-optic double ring circuit is immune toelectromagnetic interference. Upon failure of asection between two units, the communicationsystem continues to operate without interruption.If a unit were to fail, there is no effect on the com-munication with the rest of the system.

RS485 busWith this data transmission via copper conduc-tors, electromagnetic interference is largely elimi-nated by the use of twisted-pair conductors. Uponfailure of a unit, the remaining system continuesto operate without any faults.

Star structureThe relays are connected with a fiber-optic cablewith a star structure to the control unit. The failureof one relay/connection does not affect the others.

Depending on the relay type, the following proto-cols are available:

IEC 61850 protocol

Since 2004 the Ethernet-based IEC 61850 protocolis the worldwide standard for protection and con-trol systems used by power supply corporations.Siemens is the first manufacturer to support thisstandard. By means of this protocol, informationcan also be exchanged directly between bay unitsso as to set up simple masterless systems for bayand system interlocking. Access to the units viathe Ethernet bus will also be possible with DIGSI.

Fig. 2/27PROFIBUS:Electrical RS485 bus wiring

Fig. 2/28IEC 60870-5-103:Star structure withfiber-optic cables

Note:

For further details of communication features, please referto Part 4.

Fig. 2/26Bus structure for station buswith Ethernet and IEC 61850

IEC 60870-5-103

IEC 60870-5-103 is an internationally standardizedprotocol for efficient communication between theprotection relays and the central unit. Siemens-specific extensions which are published, can be used.

PROFIBUS-DP

For connection to a SIMATIC PLC, thePROFIBUS-DP protocol is recommended. With thePROFIBUS-DP the protection relay can be directly con-nected to a SIMATIC S5/S7. The transferred data arefault data, measured values and control commands.

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SIPROTEC 4 relays

MODBUS RTU

MODBUS is also a widely utilized communicationstandard and is used in numerous automationsolutions.

DNP 3.0

DNP 3.0 (Distributed Network Protocol, version 3)is a messaging-based communication protocol.The SIPROTEC 4 units are fully Level 1 and Level 2compliant with DNP 3.0. DNP 3.0 is supported bya number of protection unit manufacturers.

Control

In addition to the protection functions, theSIPROTEC 4 units also support all control andmonitoring functions required for operating me-dium-voltage or high-voltage substations. Themain application is reliable control of switchingand other processes. The status of primary equip-ment or auxiliary devices can be obtained fromauxiliary contacts and communicated to the relayvia binary inputs.

Therefore it is possible to detect and indicate boththe OPEN and CLOSED position or a faulty orintermediate breaker position. The switchgear canbe controlled via:

Integrated operator panel

Binary inputs

Substation control system

DIGSI 4.

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Fig. 2/29 Protection engineer at work

Automation

With the integrated logic, the user can set specificfunctions for the automation of the switchgear orsubstation by means of a graphic interface (CFC).Functions are activated by means of function keys,binary inputs or via the communication interface.

Switching authority

The following hierarchy of switching authorityis applicable: LOCAL, DIGSI 4 PC program,REMOTE. The switching authority is deter-mined according to parameters or by DIGSI 4. Ifthe LOCAL mode is selected, only local switch-ing operations are possible. Every switching oper-ation and change of breaker position is stored inthe status indication memory with detailed infor-mation and time tag.

Command processing

The SIPROTEC 4 protection relays offer all func-tions required for command processing, includingthe processing of single and double commandswith or without feedback as well as sophisticatedmonitoring. Control actions using functions suchas runtime monitoring and automatic commandtermination after output check of the externalprocess are also provided by the relays. Typicalapplications are:

Single and double commands using 1, 1 plus1 common or 2 trip contacts

User-definable bay interlocking

Operating sequences combining several switchingoperations such as control of circuit-breakers,isolators (disconnectors) and earthing switches

Triggering of switching operations, indicationsor alarms by logical combination of existing infor-mation.

Assignment of command feedback

The positions of the circuit-breaker or switchingdevices are monitored by feedback signals. Theseindication inputs are logically assigned to thecorresponding command outputs. The unit cantherefore distinguish whether the indicationchanges as a consequence of switching operationor due to a spontaneous change of state.

Indication derivation

A further indication (or a command) can bederived from an existing indication. Group in-dications can also be formed. The volume ofinformation to the system interface can thus bereduced and restricted to the most importantsignals.

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Illuminated 6-line display

Navigation keys

8 configurable LEDs

Fig. 2/30SIPROTEC Compact overcurrent relay

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SIPROTEC Compact ('80 relays)

SIPROTEC Compact relays are available in 1/6of 19" wide housings with a standard height of243 mm. Their size is compatible with that ofother SIPROTEC relay families. Therefore, mixedinstallations are always possible. Versions forflush mounting and for surface mounting areavailable.

All protection wires are connected at the rear sideof the relay. The remote communication inter-faces are located at the bottom of the relay.

Besides the SIPROTEC 4 features, theSIPROTEC Compact relays offer the followingdesign benefits:

Numerical keypad/9 function keys

Two control keys

USB front port

Battery cover

Pluggable current and voltage terminal blocks

Panel builders may complete and test the wholewiring without mounting the devices. Further-more an exchange of the device is simple and se-cure because the terminal blocks and thereforethe whole wiring can remain. Beyond it the riskof open secondary circuits does not exist becausethe current transformers are integrated in theterminal block.

USB front port

The USB front port offers a modern and fastcommunication through the configuration andoperation software DIGSI 4.

Adaption to substation environment

The secondary CT rated current IN (1 A or 5 A)and all binary input thresholds are set throughaddress. Therefore it is not necessary to open thedevice. Jumpers are a thing of the past.

Remote Ethernet service interface (Port A)

The Ethernet interface was conceived for a fastaccess to a number of protection units via DIGSI.For motor protection devices it is also possible toconnect up to two external temperature monitor-ing boxes (RTD box for Ethernet) with a total of12 measuring sensors to the Ethernet service in-terface.

System/Service interface (Port B)

The following communication modules areavailable:

IEC 61850: electrical double ring or optical doublering

IEC 60870-5-103: RS232, RS485, RS485 redun-dant or optical

PROFIBUS-DP: RS485 or optical double ring

MODBUS: RS485 or optical

DNP 3.0: RS485 or optical

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Fig. 2/31 Rear view

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Fig. 2/32bCurrent terminals

Fig. 2/32aVoltage terminals

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Power supply

Two versions will cover the whole range:a) 24/48 V DCb) 60 to 250 V DC, 115 and 230 V AC

Fig. 2/33

Current terminals:

Connection

Ring cable lugs

Wire size

Wmax = 9.5 mm

d1 = 5 mm

2.6 5.2 mm2 (AWG 13-10)

Single conductors:

Conductor cross-section

Insulation skipping length

2.0 4.0 mm2 (AWG 14-11)

15 mm

Voltage terminals:

Single conductors:

Conductor cross-section

Insulation skipping length

0.5 2.5 mm2 (AWG 20-13)

12 mm

Fig. 2/34 System solution/communication

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SIPROTEC 600 relays

SIPROTEC 600 relays are available in 1/6 of 19"wide housings with a standard height of 243 mm.

Their size is compatible with that of theSIPROTEC 3 and 4 families. Therefore, mixed in-stallations are always possible. Versions for flushmounting and for surface mounting are available.

All wires (cables) are connected at the rear side ofthe relay via ring cable lugs.

Fault analysis

The SlPROTEC 600 relays supply detailed data forthe analysis of faults and for checking of operatingconditions

Fault recordsThe last 8 fault records can always be displayed. Ifa new fault occurs, the oldest will be overwritten.

Operational indicationsThis log records up to 30 internal events in the relaywith 1 ms resolution.

Fault event logsThe last 8 faults are stored. All fault event logs aretime-stamped with a resolution of 1 ms.

Serial data transmission

As standard, the units are fitted with an RS485interface. This is suitable for connection to a busand allows connection of up to 32 units via ashielded twisted pair of two-wire serial interface(use of a third conductor for earth is recom-mended but not required).

Four configurable LEDs

Two line 8-digit display

Keys for navigation and entering of settingsLS

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Typical ProtectionSchemes

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Application Circuitnumber

Circuit equipment protected Page

Cables and overhead lines 1 Radial feeder circuit 2/22

2 Ring-main circuit 2/22

3 Switch-onto-fault protection 2/23

4 Directional comparison protection (cross-coupling) 2/23

5 Distribution feeder with reclosers 2/23

6 3-pole multishot auto-reclosure (AR, ANSI 79) 2/24

7 Parallel feeder circuit 2/24

8 Reverse power monitoring at double infeed 2/25

9 Synchronization function 2/25

10 Cables or short overhead lines with infeed from both ends 2/26

11 Overhead lines or longer cables with infeed from both ends 2/26

12 Subtransmission line 2/26

13 Transmission line with reactor 2/28

14 Transmission line or cable (with wide-band communication) 2/29

15 Transmission line, breaker-and-a-half terminal 2/30

Transformers 16 Small transformer infeed 2/32

17 Large or important transformer infeed 2/32

18 Dual infeed with single transformer 2/33

19 Parallel incoming transformer feeders 2/33

20 Parallel incoming transformer feeders with bus tie 2/33

21 Three-winding transformer 2/34

22 Autotransformer 2/34

23 Large autotransformer bank 2/35

Motors 24 Small and medium-sized motors < about 1 MW 2/35

25 Large HV motors > about 1 MW 2/36

26 Cold load pickup 2/36

Generators 27 Very small generators < 500 kW 2/37

28 Small generators, typically 13 MW 2/37

29 Small generators > 13 MW 2/37

30 Medium-sized generators > 510 MWfeeding into a network with isolated neutral 2/38

31 Large generators > 50100 MWin generator transformer unit connection

2/39

32 Synchronization of generators 2/40

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Application Circuitnumber

Circuit equipment protected Page

Busbars 33 Busbar protection by o/c relays with reverse interlocking 2/40

34 High-impedance busbar protection 2/41

35 Low-impedance busbar protection 7SS60 2/41

36 Low-impedance busbar protection 7SS5 2/41

Networks 37 Load shedding 2/42

38 Load shedding with rate-of-frequency-change protection 2/42

39 Trip circuit supervision (ANSI 74TC) 2/42

40 Disconnecting facility 2/43

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Cables and overhead lines

1 Radial systems

Notes:1) Auto-reclosure 79 only with overhead lines.2) Negative sequence overcurrent protection 46 as

sensitive backup protection against unsymmet-rical faults.

General hints: The relay at the far end (D) is set with shortest

operating time.Relays further upstream have to be time-gradedagainst the next downstream relay in steps ofabout 0.3 seconds.

Inverse time or definite time can be selectedaccording to the following criteria:

Definite time:Source impedance large compared to the lineimpedance, i.e. small current variation betweennear and far end faults

Inverse time:Longer lines, where the fault current is muchless at the far end of the line than at the localend.

Very or extremely inverse time:Lines where the line impedance is large com-pared to the source impedance (high differencefor close-in and remote faults) or lines, wherecoordination with fuses or reclosers is neces-sary. Steeper characteristics also provide higherstability on service restoration (cold load pickupand transformer inrush currents).

2 Ring-main circuit

General hints: Operating time of overcurrent relays to be coordi-

nated with downstream fuses of load transformers.(Preferably very inverse-time characteristic withabout 0.2 s grading-time delay)

Thermal overload protection for the cables(option)

Negative sequence overcurrent protection 46 assensitive protection against unsymmetrical faults(option).

Fig. 2/35

Fig. 2/36*) Alternatives:

7SJ45/46, 7SJ61, 7SJ80

*) Alternatives:7SJ45/46, 7SJ61

Transformerprotectionsee Fig. 2/52

Transformerprotectionsee Fig. 2/55

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Fig. 2/37

3 Switch-onto-fault protection

If switched onto a fault, instantaneous trippingcan be effected. If the internal control function isused (local, via binary input or via serial inter-face), the manual closing function is availablewithout any additional wiring. If the controlswitch is connected to a circuit-breaker bypassingthe internal control function, manual detectionusing a binary input is implemented.

4 Directional comparison protection(cross-coupling)

It is used for selective protection of sections fedfrom two sources with instantaneous tripping, i.e.without the disadvantage of time coordination.The directional comparison protection is suitableif the distances between the protection stations arenot significant and pilot wires are available forsignal transmission. In addition to the directionalcomparison protection, the directional coordi-nated time-overcurrent protection is used forcomplete selective backup protection. If operatedin a closed-circuit connection, an interruption ofthe transmission line is detected.

5 Distribution feeder with reclosers

General hints: The feeder relay operating characteristics, delay

times and auto-reclosure cycles must be carefullycoordinated with downstream reclosers, sectio-nalizers and fuses.The 50/50N instantaneous zone is normally set toreach out to the first main feeder sectionalizingpoint. It has to ensure fast clearing of close-infaults and prevent blowing of fuses in this area(fuse saving). Fast auto-reclosure is initiated inthis case.Further time-delayed tripping and reclosure steps(normally 2 or 3) have to be graded against therecloser.

The o/c relay should automatically switch over toless sensitive characteristics after long breaker in-terruption times to enable overriding of subse-quent cold load pickup and transformer inrushcurrents.

Fig. 2/38

Fig. 2/39

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6 3-pole multishot auto-reclosure (AR, ANSI 79)

Auto-reclosure (AR) enables 3-phase auto-reclo-sing of a feeder which has previously been discon-nected by overcurrent protection.

The SIPROTEC 7SJ61 allows up to 9 reclosingshots. The first four dead times can be set individ-ually. Reclosing can be blocked or initiated by abinary input or internally. After the first trip in areclosing sequence, the high-set instantaneouselements (I>>>, I>>, IE>>) can be blocked. Thisis used for fuse saving applications and other simi-lar transient schemes using simple overcurrent re-lays instead of fuses. The low-set definite-time (I>,IE>) and the inverse-time (Ip, IEp) overcurrent ele-ments remain operative during the entiresequence.

7 Parallel feeder circuit

General hints: This circuit is preferably used for the reliable sup-

ply of important consumers without significantinfeed from the load side.

The 67/67N directional overcurrent protectiontrips instantaneously for faults on the protectedline. This saves one time-grading interval for theo/c relays at the infeed.

The 51/51N o/c relay functions must be time-graded against the relays located upstream.

Fig. 2/40

Fig. 2/41

*) Alternatives:7SJ60, 7SJ62/63/64, 7SJ80

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Fig. 2/43

9 Synchronization function

Note:1) Also available in relays 7SA6, 7SD5, 7SA522,

7VK61.

General hints: When two subnetworks must be interconnected,

the synchronization function monitors whetherthe subnetworks are synchronous and can be con-nected without risk of loosing stability.

This synchronization function can be applied inconjunction with the auto-reclosure function aswell as with the control function CLOSE com-mands (local/remote).

8 Reverse-power monitoring at double infeed

If a busbar is fed from two parallel infeeds and afault occurs on one of them, only the faulty infeedshould be tripped selectively to enable supply tothe busbar to continue from the remaining sup-ply. Unidirectional devices that can detect ashort-circuit current or energy flow from thebusbar towards the incoming unit should be used.Directional time-overcurrent protection is usuallyset via the load current. However, it cannot clearweak-current faults. The reverse-power protectioncan be set way lower than the rated power, thusalso detecting the reverse-power flow of weak-cur-rent faults with fault currents significantly belowthe load current.

Fig. 2/42

*) Alternatives:7SJ62, 7SJ80

Fig. 2/44

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10 Cables or short overhead lines with infeedfrom both ends

Notes:1) Auto-reclosure only with overhead lines

2) Differential protection options:

Type 7SD5 or 7SD610 with direct fiber-optic connection up to about 100 km or via a64 kbit/s channel (optical fiber, microwave)

Type 7SD52 or 7SD610 with 7XV5662 (CC-CC)with 2 and 3 pilot-wires up to about 30 km

Type 7SD600 with 2 pilot-wires up to 12 km7SD600 is a cost-effective solution where onlythe function 87L is required (external currentsummation transformer 4AM4930 deliveredseparately).

3) Functions 49 and 79 only with 7SD5 and7SD610 relays.

11 Overhead lines or longer cables with infeedfrom both ends

Notes:1) Teleprotection logic 85 for transfer trip or

blocking schemes. Signal transmission via pilotwire, power-line carrier, digital network oroptical fiber (to be provided separately). Theteleprotection supplement is only necessary iffast fault clearance on 100 % line length is re-quired, i.e. second zone tripping (about 0.3 sdelay) cannot be accepted for far end faults.For further application hints of teleprotectionschemes, please refer to the table on page 2/27.

2) Directional earth-fault protection 67N withinverse-time delay against high-resistance faults

3) Single or multishot auto-reclosure 79 only withoverhead lines.

12 Subtransmission line

Note:1) Connection to open delta winding if available.

Relays 7SA6/522 and 7SJ62 can, however, alsobe set to calculate the zero-sequence voltageinternally.

General hints: Distance teleprotection is proposed as main, and

time-graded directional overcurrent as backupprotection.

The 67N function of 7SA6/522 provides addi-tional high-resistance earth-fault protection.It can be used in parallel with the 21/21N function.

Recommended teleprotection schemes:PUTT on medium and long lines with phase shiftcarrier or other secure communication channelPOTT on short lines.BLOCKING with On/Off carrier (all line lengths).

Fig. 2/45

Fig. 2/46

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Permissive underreachtransfer trip (PUTT)

Permissive overreachtransfer trip (POTT)

Blocking Unblocking

Preferredapplication

Signaltransmissionsystem

Dependable and secure communication channel:

Power line carrier with frequency shift modulation.HF signal coupled to 2 phases of the protected line,or even better, to a parallel circuit to avoidtransmission of the HF signal through the faultlocation.

Microwave radio, especially digital (PCM)

Fibre-optic cables

Reliable communicationchannel (only requiredduring external faults)

Power line carrier withamplitude modulation(ON/OFF). The samefrequency may be usedon all terminals)

Dedicated channel withcontinuous signal transfer

Power line carrier withfrequency shift keying.Continuous signaltransmission must bepermitted.

Characteristicof line

Best suited for longerlines - where theunderreach zoneprovides sufficientresistance coverage

Excellent coverage onshort lines in the presenceof fault resistance.

Suitable for the protectionof multi-terminal lines withintermediate infeed

All line types - preferredpractice in the USA

Same as POTT

Advantages Simple technique

No coordination ofzones and times withthe opposite endrequired.The combination ofdifferent relay typestherefore presents noproblems

Can be applied withoutunderreaching zone 1 stage(e.g. overcompensated seriescompensated lines)

Can be applied on extremelyshort lines (impedance lessthan minimum relay setting)

Better for parallel lines as mu-tual coupling is not critical forthe overreach zone

Weak infeed terminals are noproblem. (Echo and WeakInfeed logic is included)

Same as POTT Same as POTT but:

If no signal is received(no block and no un-block) then tripping bythe overreach zone is re-leased after 20 ms

Drawbacks Overlapping of the zone 1reaches must be ensured.On parallel lines, teed feed-ers and tapped lines, the in-fluence of zero sequencecoupling and intermediateinfeeds must be carefullyconsidered to make sure aminimum overlapping ofthe zone 1 reach is alwayspresent.

Not suitable for weakinfeed terminals

Zone reach and signal timingcoordination with the remoteend is necessary (current rever-sal)

Same as POTT

Slow tripping - allteleprotection trips mustbe delayed to wait for theeventual blocking signal

Continuous channel moni-toring is not possible

Same as POTT

Application criteria for frequentlyused teleprotection schemes

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13 Transmission line with reactor

Notes:1) 51N only applicable with earthed reactor

neutral.

2) If phase CTs at the low-voltage reactor side arenot available, the high-voltage phase CTs andthe CT in the neutral can be connected to arestricted earth-fault protection using one7VH60 high-impedance relay.

General hints: Distance relays are proposed as main 1 and main 2

protection. Duplicated 7SA513 is recommendedfor series-compensated lines.

Operating time of the distance relays in the rangeof 15 to 25 ms depending on the particular faultcondition.These tripping times are valid for faults in theunderreaching distance zone (80 to 85 % of theline length). Remote end faults must be clearedby the superimposed teleprotection scheme.Its overall operating time depends on the signaltransmission time of the channel, typically 15 to20 ms for frequency shift audio-tone PLC ormicrowave channels, and lower than 10 ms forON/OFF PLC or digital PCM signaling viaoptical fibers.

Teleprotection schemes based on distance relaystherefore have operating times in the order of25 - 30 ms with digital PCM coded communica-tion. With state-of-the-art two-cycle circuit-breakers, fault clearing times well below 100 ms(4 to 5 cycles) can normally be achieved.

Dissimilar carrier schemes are recommendedfor main 1 and main 2 protection, for examplePUTT, and POTT or Blocking/Unblocking.

Both 7SA522 and 7SA6 provide selectivesingle-pole and/or three-pole tripping and auto-reclosure.The earth-current directional comparisonprotection 67N of the 7SA513 relay uses phaseselectors based on symmetrical components.Thus, single-pole auto-reclosure can also beexecuted with high-resistance faults.The 67N function of the 7SA6/522 relay canalso be used as time-delayed directional over-current backup.

The 67N functions are provided as high-impe-dance fault protection. 67N is often used with anadditional channel as separate carrier scheme. Useof a common channel with distance protection isonly possible if the mode is compatible (e.g.POTT with directional comparison). The 67Nmay be blocked when function 21/21N picks up.Alternatively, it can be used as time-delayedbackup protection.

Fig. 2/47

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14 Transmission line or cable(with wide-band communication)

General hints: Digital PCM-coded communication

(with n x 64 kbit/s channels) between line ends isbecoming more and more frequently available,either directly by optical or microwavepoint-to-point links, or via a general purposedigital communication network.

In both cases, the relay type current differentialprotection 7SD52/61 can be applied. It providesabsolute phase and zone-selectivity by phase-segregated measurement, and is not affected bypower swing or parallel line zero-sequence cou-pling effects. It is furthermore a current-onlyprotection that does not need VT connection.For this reason, the adverse effects of CVT tran-sients are not applicable.

This makes it in particular suitable for doubleand multi-circuit lines where complex fault sit-uations can occur.

The 7SD5/61 can be applied to lines up to about120 km in direct relay-to-relay connection viadedicated optical fiber cores (see also applica-tion 10), and also to much longer distances upto about 120 km by using separate PCM devicesfor optical fiber or microwave transmission.

The 7SD5/61 then uses only a small part(64-512 kbit/s) of the total transmission capac-ity being in the order of Mbits/s.

The 7SD52/61 protection relays can be combinedwith the distance relay 7SA52 or 7SA6 to form aredundant protection system with dissimilar mea-suring principles complementing each other. Thisprovides the highest degree of availability. Also,separate signal transmission ways should be usedfor main 1 and main 2 line protection, e.g. opticalfiber or microwave, and power-line carrier (PLC).

The current comparison protection has a typicaloperating time of 15 ms for faults on 100 % linelength including signaling time.

General hints for Fig. 2/49: SIPROTEC 7SD5 offers fully redundant differen-

tial and distance relays accommodated in one sin-gle bay control unit and provides high-speed oper-ation of both relays and excellent fault coverage,even under complicated conditions. Precise dis-tance-to-fault location avoids time consuming linepatrolling and reduces the down time of the line toa minimum.

The high-speed distance relay operates fully in-dependent from the differential relay. Back-upzones provide remote back-up for upstream anddownstream lines and other power system com-ponents.

Fig. 2/48

Fig. 2/49

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15 Transmission line,breaker-and-a-half terminal

Notes for Fig. 2/50 and 2/51:1) When the line is switched off and the line isola-

tor is open, high through-fault currents in thediameter may cause maloperation of the dis-tance relay due to unequal CT errors (satura-tion).

Normal practice is therefore to block the dis-tance protection (21/21N) and the directionalearth-fault protection (67N) under thiscondition via an auxiliary contact of the lineisolator. Instead, a standby overcurrent func-tion (50/51N, 51/51N) is released to protect theremaining stub between the breakers (stubprotection).

2) Overvoltage protection only with 7SA6/52.

General hints: The protection functions of one diameter of a

breaker-and-a-half arrangement are shown.

The currents of two CTs have each to be summedup to get the relevant line currents as input formain 1 and 2 line protection.

The location of the CTs on both sides of the cir-cuit-breakers is typical for substations with dead-tank circuit-breakers. Live-tank circuit-breakersmay have CTs only on one side to reduce cost. Afault between circuit-breakers and CT (end fault)may then still be fed from one side even when thecircuit-breaker has opened. Consequently, finalfault clearing by cascaded tripping has to be ac-cepted in this case.

The 7VK61 relay provides the necessary end faultprotection function and trips the circuit-breakersof the remaining infeeding circuits.

Fig. 2/50

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2/31

General hints for Fig. 2/50 and 2/51:

For the selection of the main 1 and main 2 lineprotection schemes, the comments of applicationexamples 13 and 14 apply.

Auto-reclosure (79) and synchro-check function(25) are each assigned directly to the circuit-breakers and controlled by main 1 and 2 line pro-tection in parallel. In case of a line fault, both adja-cent circuit-breakers have to be tripped by the lineprotection. The sequence of auto-reclosure of bothcircuit-breakers or, alternatively, the auto-reclosure of only one circuit-breaker and the man-ual closure of the other circuit-breaker, may bemade selectable by a control switch.

A coordinated scheme of control circuits is neces-sary to ensure selective tripping interlocking andreclosing of the two circuit-breakers of one line(or transformer feeder).

The voltages for synchro-check have to be selectedaccording to the circuit-breaker and disconnector(isolator) position by a voltage replica circuit.

General hints for Fig. 2/51:

In this optimized application, the 7VK61 is onlyused for the center breaker. In the line feeders,functions 25, 79 and BF are also performed bytransmission line protection 7SA*.

Notes 1) and 2) see page 2/30.

Fig. 2/51

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Transformers

16 Small transformer infeed

General hints: Earth faults on the secondary side are detected by

current relay 51N which, however, has to be time-graded against downstream feeder protection re-lays.The restricted earth-fault relay 87N can optionallybe applied to achieve fast clearance of earth faultsin the transformer secondary winding.Relay 7VH60 is of the high-impedance type andrequires class X CTs with equal transformationratio.

Primary circuit-breaker and relay may be replacedby fuses.

17 Large or important transformer infeed

General hint: Relay 7UT612 provides numerical ratio and vector

group adaptation. Matching transformers as usedwith traditional relays are therefore no longer ap-plicable.

Notes:1) If an independent high-impedance-type

earth-fault function is required, the 7VH60earth-fault relay can be used instead of the 87Ninside the 7UT612. However, class X CT coreswould additionally be necessary in this case.(See small transformer protection)

2) 51 and 51N may be provided in a separate7SJ60 if required.

Fig. 2/52

Fig. 2/53

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18 Dual infeed with single transformer

General hints: Line CTs are to be connected to separate stabiliz-

ing inputs of the differential relay 87T in order toassure stability in case of line through-fault cur-rents.

Relay 7UT613 provides numerical ratio and vectorgroup adaptation. Matching transformers, as usedwith traditional relays, are therefore no longer ap-plicable.

19 Parallel incoming transformer feeders

Note:1) The directional functions 67 and 67N do

not apply for cases where the transformersare equipped with transformer differentialrelays 87T.

20 Parallel incoming transformer feederswith bus tie

General hints: Overcurrent relay 51, 51N each connected as a

partial differential scheme. This provides simpleand fast busbar protection and saves one time-grading step.

Fig. 2/54

Fig. 2/55

Fig. 2/56

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21 Three-winding transformer

Notes:1) The zero-sequence current must be blocked be-

fore entering the differential relay with a deltawinding in the CT connection on the trans-former sides with earthed starpoint. This is toavoid false operation during external earthfaults (numerical relays provide this functionby calculation). About 30 % sensitivity, how-ever, is then lost in case of internal faults.Optionally, the zero-sequence current can beregained by introducing the winding neutralcurrent in the differential relay (87T). Relaytype 7UT613 provides two current inputs forthis purpose. By using this feature, the earth-fault sensitivity can be upgraded again to itsoriginal value.

Restricted earth-fault protection (87T) is op-tional. It provides backup protection for earthfaults and increased earth-fault sensitivity(about 10 % IN, compared to about 20 to 30 %IN of the transformer differential relay).Separate class X CT-cores with equal transmis-sion ratio are additionally required for this pro-tection.

2) High impedance and O/C in one 7SJ61.

General hint: In this example, the transformer feeds two differ-

ent distribution networks with cogeneration.Restraining differential relay inputs are thereforeprovided at each transformer side.If both distribution networks only consume loadand no through-feed is possible from one MV net-work to the other, parallel connection of the CTsof the two MV transformer windings is admissibleallowing the use of a two-winding differential relay(7UT612).

22 Autotransformer

Notes:1) 87N high-impedance protection requires spe-

cial class X current transformer cores withequal transformation ratio.

2) The 7SJ60 relay can alternatively be connectedin series with the 7UT613 relay to save this CTcore.

General hint: Two different protection schemes are provided:

87T is chosen as low-impedance three-windingversion (7UT613). 87N is a single-phase high-impedance relay (7VH60) connected as restrictedearth-fault protection. (In this example, it is as-sumed that the phase ends of the transformerwinding are not accessible on the neutral side, i.e.there exists a CT only in the neutral earthing con-nection.)

Fig. 2/57

Fig. 2/58

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23 Large autotransformer bank

General hints: The transformer bank is connected in a

1 circuit-breaker arrangement.Duplicated differential protection is proposed:

Main 1: Low-impedance differential protection87TL (7UT613) connected to the transformerbushing CTs.

Main 2: High-impedance differential overallprotection 87TL (7VH60). Separate class Xcores and equal CT ratios are required for thistype of protection.

Backup protection is provided by distance protec-tion relay (7SA52 and 7SA6), each looking withan instantaneous first zone about 80 % into thetransformer and with a time-delayed zone beyondthe transformer

The tertiary winding is assumed to feed a smallstation supply network with isolated neutral.

Motors 1)

24 Small and medium-sized motors< about 1 MW

a)With effective or low-resistanceearthed infeed (IE IN Motor)

General hint: Applicable to low-voltage motors and high-vol-

tage motors with low-resistance earthed infeed(IE IN Motor)

b) With high-resistance earthed infeed

(IE IN Motor)

Notes:1) Core-balance CT.2) Sensitive directional earth-fault protection

67N only applicable with infeed from isolatedor Peterson-coil-earthed network(For dimensioning of the sensitive directionalearth-fault protection, see also applicationcircuit No. 30)

3) The 7SJ602 relay can be applied for isolated andcompensated networks.

Fig. 2/59

Fig. 2/60

Fig. 2/61

1)For further applications of motor protection see part 12 of this catalog.

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25 Large HV motors > about 1 MW

Notes:1) Core-balance CT.

2) Sensitive directional earth-fault protection67N only applicable with infeed from isolatedor Peterson-coil-earthed network

3) This function is only needed for motors wherethe startup time is longer than the safe stall timetE. According to IEC 60079-7, the tE-time is thetime needed to heat up AC windings, when car-rying the starting current IA, from thetemperature reached in rated service and atmaximum ambient temperature to the limitingtemperature. A separate speed switch is used tosupervise actual starting of the motor. The mo-tor circuit-breaker is tripped if the motor doesnot reach speed in the preset time. The speedswitch is part of the motor supply itself.

4) Pt100, Ni100, Ni120

5) 49T only available with external temperaturemonitoring device (7XV5662)

26 Cold load pickup

By means of a binary input which can be wiredfrom a manual close contact, it is possible toswitch the overcurrent pickup settings to less sen-sitive settings for a programmable amount oftime. After the set time has expired, the pickupsettings automatically return to their original set-ting. This can compensate for initial inrush whenenergizing a circuit without compromising thesensitivity of the overcurrent elements duringsteady state conditions.

Fig. 2/62

Fig. 2/63

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27 Generators < 500 kW(Fig. 2/64 and 2/65)

Note:1) If a core-balance CT is provided for sensitive

earth-fault protection, relay 7SJ602 with sepa-rate earth-current input can be used.

28 Generators, typically 13 MW(Fig. 2/66)

Note:1) Two VTs in V connection are also sufficient.

29 Generators > 13 MW(Fig. 2/67)

Notes:1) Functions 81 and 59 are only required where

prime mover can assume excess speed and thevoltage regulator may permit rise of outputvoltage above upper limit.

2) Differential relaying options: Low-impedance differential protection 87. Restricted earth-fault protection with low ohmic

resistance-earthed neutral (see Fig. 2/65).

Fig. 2/64

With solidly-earthed neutral

Generators

Fig. 2/66

Fig. 2/67

Fig. 2/65

With resistance-earthed neutral

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For the most sensitive setting of 2 mA, we there-fore need 20 mA secondary earth current, corre-sponding to (60/1) x 20 mA = 1.2 A primary

If sufficient capacitive earth current is not avail-able, an earthing transformer with resistivezero-sequence load can be installed as earth-current source at the station busbar.The smallest standard earthing transformerTGAG 3541 has a 20 s short time rating ofSG = 27 kVA

In a 5 kV network, it would deliver:

IS

VG 20 s

G

N

VA

5000 VA=

=

=

3 3 27 0009 4

,.

corresponding to a relay input current of9.4 A x 1/60 A = 156 mA. This would provide a90 % protection range with a setting of about15 mA, allowing the use of 4 parallel connectedcore-balance CTs. The resistance at the 500 Vopen-delta winding of the earthing transformerwould then have to be designed for

RB = V2SEC /SG = 500 V2 / 27,000 VA = 9.26 (27 kW, 20 s).

For a 5 MVA machine and 600/5 A CTs withspecial calibration for minimum residual falsecurrent, we would get a secondary current ofIG SEC = 9.4 A/ (600/5) = 78 mA.

With a relay setting of 12 mA, the protection

range would in this case be 100 112

78

= 85 %.

Notes:See following page

Relay earth-currentinput connected to:

Minimum relay setting: Comments:

Core-balance CT 60/1 A:1 single CT2 parallel CTs3 parallel Cts4 parallel CTs

2 mA5 mA8 mA

12 mA

Three-phase CTs inresidual (Holmgreen)connection

1 A CT: 50 mA5 A CT: 200 mA

In general not suitablefor sensitive earth-faultprotection

Three-phase CTs inresidual (Holmgreen)connection with specialfactory calibration tominimum residual falsecurrents ( 2 mA)

2 - 3 of secondaryrated CT current In SEC10 - 15 mA with 5 A CTs

1 A CTs are notrecommended inthis case

29 Generators > 510 MWfeeding into a network with isolated neutral(Fig. 2/68)

General hints:

The setting range of the directional earth-faultprotection 67N in the 7UM6 relay is 21000 mA.Depending on the current transformer accuracya certain minimum setting is required to avoidfalse operation on load or transient currents.

In practice, efforts are generally made to protectabout 90 % of the machine winding, measuredfrom the machine terminals. The full earth currentfor a terminal fault must then be ten times the set-ting value which corresponds to the fault currentof a fault at 10 % distance from the machine neu-tral.

Fig. 2/68

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