SIPROTEC 4 Catalog

SIPROTEC 4, Protection, Operating Programs, Communication, Overcurrent Protection, Distance Protection, Line Differential Protection, Transformer Differential Protection, Busbar Differential Protection, Relays for Various Protection Applications, Generator Protection, Motor Protection, Substation Automation, DIGSI 4

SIPROTEC, 4;, Protection;, Operating, Programs;, Communication;, Overcurrent, Protection;, Distance, Protection;, Line, Differential, Protection;, Transformer, Differential, Protection;, Busbar, Differential, Protection;, Relays, for, Various, Protection, Applications;, Generator, Protection;, Motor, Protection;, Substation, Automation;, DIGSI, 4

Siemens AG

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SIP4 E8 8.1 2020 en

Protection, control, measurement, and automation functions
SIPROTEC 4 Devices
Catalog SIP · Edition No. 8 / 8.1
siemens.com/siprotec

Overview of Siemens Protection Catalogs

Documentation

Selection guide
for SIPROTEC and Reyrolle

SIPROTEC 5
Catalog

SIPROTEC Compact
Catalog

SIPROTEC 4
Catalog

Accessories
Catalog

Reyrolle
Catalogs

Manuals

Overview of the Documentation

SIPROTEC 4 Catalog: This catalog describes the features of the device series SIPROTEC 4.
Selection guide for SIPROTEC and Reyrolle: The selection guide offers an overview of the device series of the Siemens protection devices, and a device selection table.
SIPROTEC Compact Catalog: The SIPROTEC Compact catalog describes the features of the SIPROTEC Compact series and presents the available devices and their application possibilities.
SIPROTEC 5 Catalogs: The catalog describes the features of the SIPROTEC 5 system and device-specific features such as scope of functions, hardware and application.

Accessories Catalog: This catalog describes the accesories for protection, power quality and substation automation devices.
Reyrolle Catalogs: The Reyrolle catalogs describes the features such as scope of functions, hardware and application.
Manuals: The manuals describe, among others, the operation, installation, the technical data, of the devices.

SIPROTEC 4
Catalog SIP · Edition No. 8 / 8.1
Updates Ed8.1: · Cancellation due to phase out
6MD61, 6MD63, 7SJ63 and 7UM61 · Cancellation SIPROTEC 4 Tutorial · SIPROTEC 7SJ66 small updates Invalid: Catalog SIP · Edition No. 8 and No. 7
The products and systems described in this catalog are manufactured and sold according to a certified management system (acc. to ISO 9001, ISO 14001 and BS OHSAS 18001).

Contents

1. Product Selection 1/1 to 1/6
2. Overview/Applications 2/1 to 2/48
3. Operating Programs 3/1 to 3/8
4. Communication 4/1 to 4/12
5. Overcurrent Protection 5/1 to 5/114
6. Distance Protection 6/1 to 6/70
7. Line Differential Protection 7/1 to 7/56
8. Transformer Differential Protection 8/1 to 8/38
9. Busbar Differential Protection 9/1 to 9/18
10. Relays for Various Protection Applications 10/1 to 10/18
11. Generator Protection 11/1 to 11/72
12. Substation Automation 12/1 to 12/22
13. Appendix 13/1 to 13/22

1 2 3 4 5 6 7 8 9 10 11 12 13

Siemens SIP · Edition No. 8.1 1

Product Index

Type

Description

DIGSI 4

Operating software for SIPROTEC 4 und Compact

IEC 61850 System Configurator Operating software for all IEC 61850 devices

SIGRA 4

6MD66

Evaluation software for fault records High-voltage bay control unit

7SA522

Distance protection relay for transmission lines

7SA6

Distance protection relay for all voltage levels

7SD52/53

Multi-end differential and distance protection in one relay

7SD61

Differential protection relay for 2 line ends

7SJ61

Multifunction protection relay

7SJ62

Multifunction protection relay

7SJ64

Multifunction protection relay with synchronization

7SJ66

Multifunction protection relay with local control

7SS52

Distributed busbar and breaker failure protection

7UM62

Multifunction generator, motor and transformer protection relay

7UT6

Differential protection relay for transformers, generators, motors and busbars

7VE6

Multifunction paralleling device

7VK61

Breaker management relay

7VU683

High Speed Busbar Transfer

Page 3/3 3/5 3/7 12/3 6/39 6/3 7/25 7/3 5/3 5/25 5/53 5/87 9/3 11/3 8/3 11/33 10/3 11/53

2 Siemens SIP · Edition No. 8.1

Function overview

Relay Functions

1
Page 1/2

Function overview
SIPROTEC 4 devices series
Device application
1

2 3 4 5 6 7 8 9 10 11 12 13 14

ANSI

Functions

Protection functions for 3-pole tripping

Protection functions for 1-pole tripping

Locked rotor protection

21/21N Distance protection

Overexcitation protection

Synchrocheck, synchronizing function

Undervoltage protection

27TN/59TN Stator ground fault 3rd harmonics

Undervoltage-controlled reactive power protection

Directional power supervision

Undercurrent, underpower

Temperature supervision

Underexcitation protection

Unbalanced-load protection

Negative-sequence system overcurrent protection

Phase-sequence-voltage supervision

Overvoltage protection, negative-sequence system

Starting-time supervision

Thermal overload protection

50/50N Definite time-overcurrent protection

SOFT

Instantaneous tripping at switch onto fault

50Ns

Sensitive ground-current protection

Intermittent ground fault protection

50EF

End fault protection

50BF

Circuit-breaker failure protection

51/51N Inverse time-overcurrent protection

50L

Load-jam protection

51C

Cold load pickup

51V

Voltage dependent overcurrent protection

Power factor

Overvoltage protection

59N

Overvoltage protection, zero-sequence system

59R, 27R Rate-of-voltage-change protection

60FL

Fuse-Failure-Monitor

Sensitive ground-fault protection (machine)

Restart inhibit

Abbr. 3-pole 1-pole I> + V< Z<, V/(V,I) V/f Sync V< V0<,>(3.Harm.) Q>/V< P<>, Q<> I<, P< > 1/XD I2> I2>, I2/I1> LA, LB, LC V>2 I2start , I2t I>
INs> Iie>
CBFP IP, INp I>L
t=f(I)+V< cos V> V0> dV/dt
I2t

= basic = optional (additional price) = not available

1) via CFC More functions on page 1/4

You will find the whole function overview of the SIPROTEC devices at: www.siemens.com/protection

15
1/2 Siemens SIP · Edition No. 8

Type 7SA522 7SA61 7SA63 7SA64 7SD610 7SD5

Distance protection

Line differential protection

Device application

Generator and motor protection

Transformer protection

Function overview
SIPROTEC 4 devices series

Busbar

Bay controller Breaker

Synchroniz High Speed

protection

management

ing

Busbar Transfer

7SJ61 7SJ62 7SJ64 7SJ66 7UM62 7UT612 7UT613 7UT63 7SS52 6MD66 7VK61 7VE6 7VU683

Table continued on next page

15
Siemens SIP · Edition No. 8.1 1/3

Function overview
SIPROTEC 4 devices series
Device application
1

2 3 4 5 6 7 8 9 10 11 12

ANSI 67 67N 67Ns
67Ns 68 74TC 78 79 81 81R
85 86 87 87N
FL

Functions

Abbr.

Directional time-overcurrent protection, phase Directional time-overcurrent protection for ground-faults Sensitive ground-fault detection for systems with resonant or isolated neutral
Directional intermittent ground fault protection

I>,IP (V,I) IN>, INP (V,I)
INs>, INsP (V,I)
Iie dir>

Power-swing blocking

Z/t

Trip-circuit supervision

TCS

Out-of-step protection

Z/t

Automatic reclosing

Frequency protection

f<, f>

Rate-of-frequency-change protection

df/dt

Vector-jump protection Teleprotection

Lockout

Differential protection

Differential ground-fault protection

Broken-wire detection for differential protection

Fault locator

Further Functions

Measured values

Switching-statistic counters

Logic editor

CFC switching sequences for control applications

Inrush-current detection

External trip initiation

High Speed busbar transfer function

Fault recording of analog and binary signals

Monitoring and supervision

Protection interface, serial

No. Setting groups

Changeover of setting group

Circuit breaker test

= basic = optional (additional price) = not available 1) via CFC
You will find the whole function overview of the SIPROTEC devices at: www.siemens.com/protection

15
1/4 Siemens SIP · Edition No. 8

Type 7SA522 7SA61 7SA63 7SA64 7SD610 7SD5

Distance protection

Line differential protection

444444

Device application

Function overview
SIPROTEC 4 devices series

Generator

Transformer

Busbar Bay controller Breaker

Synchroniz High Speed

and motor protection

protection

management

ing

Busbar Transfer

7SJ61 7SJ62 7SJ64 7SJ66 7UM62 7UT612 7UT613 7UT63 7SS52 6MD66 7VK61 7VE6 7VU683

444

15
Siemens SIP · Edition No. 8.1 1/5

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
1/6 Siemens SIP · Edition No. 8

Overview / Applications
SIPROTEC Device Series Typical protection schemes Protection coordination

Page

2/3

2/16

2/37

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
2/2 Siemens SIP · Edition No. 8

Overview
SIPROTEC Device Series

Solutions for today's and future power supply systems

for more than 100 years SIPROTEC has established itself on the energy market for

decades as a powerful and complete system family of numerical

protection relays and bay controllers from Siemens.

SIPROTEC protection relays from Siemens can be consistently

used throughout all applications in medium and high voltage.

With SIPROTEC, you have their systems firmly and safely under

control, and have the basis to implement cost-efficient solutions

for all duties in modern, intelligent and "smart" grids. Users can combine the units of the different SIPROTEC device series at

will for solving manifold duties because SIPROTEC stands for

continuity, openness and future-proof design.

As the innovation driver and trendsetter in the field of protection systems for more than 100 years, Siemens helps you to design

their grids in an intelligent, ecological, reliable and efficient way,

and to operate them economically. As a pioneer, Siemens has

decisively influenced the development of numerical protection systems (Fig. 2/2). The first application went into operation in

Fig. 2/1 SIPROTEC Relay Family

Würzburg, Germany, in 1977. Consistent integration of protec-

tion and control functions for all SIPROTEC devices was the

How can system operators benefit from this experience?

innovation step in the 90ies. After release of the communication standard IEC 61850 in the year 2004, Siemens was the first manufacturer worldwide to put a system with this communica-

·Proven and complete applications ·Easy integration into your system

tion standard into operation. In the meantime we have delivered ·Highest quality of hardware and functionality

more than 500,000 devices with IEC 61850 included.

·Excellent operator friendliness of devices and tools

Many users have approved SIPROTEC protection devices for use ·Easy data exchange between applications

in their power systems. The devices have also been certified by ·Extraordinary consistency between product- and system-

independent test institutes and universities (KEMA, EPRI, LOYD,

engineering

UR Laboratories).

·Reduced complexity by easy operation ·Siemens as a reliable, worldwide operating partner.

Information about SIPROTEC 5 and SIPROTEC Compact product

families can be found in the related catalogs or at:

www.siemens.com/siprotec

Fig. 2/2 SIPROTEC Pioneer over generations

15
Siemens SIP · Edition No. 8 2/3

Overview
SIPROTEC Device Series

1 2 3 4 5 6 7 8 9 10 11

SIPROTEC Compact Maximum protection-minimum space
Perfect protection, smallest space reliable and flexible protection for energy distribution and industrial systems with minimum space requirements. The devices of the SIPROTEC Compact family offer an extensive variety of functions in a compact and thus space-saving ¹/ x 19" housing. The devices can be used as main protection in medium-voltage applications or as back-up protection in high-voltage systems.
SIPROTEC Compact provides suitable devices for many applications in energy distribution, such as the protection of feeders, lines or motors. Moreover, it also performs tasks such as system decoupling, load shedding, load restoration, as well as voltage and frequency protection.
The SIPROTEC Compact series is based on millions of operational experience with SIPROTEC 4 and a further-developed, compact hardware, in which many customer suggestions were integrated. This offers maximum reliability combined with excellent functionality and flexibility.
·Simple installation by means of pluggable current and voltage terminal blocks
·Thresholds adjustable via software (3 stages guarantee a safe and reliable recording of input signals)
·Easy adjustment of secondary current transformer values (1 A/5 A) to primary transformers via DIGSI 4
·Quick operations at the device by means of 9 freely programmable function keys
·Clear overview with six-line display
·Easy service due to buffer battery replaceable at the front side
·Use of standard cables via USB port at the front
·Integration in the communication network by means of two further communication interfaces
·Integrated switch for low-cost and redundant optical and electrical Ethernet rings
·Ethernet redundancy protocols RSTP, PRP and HSR for highest availability
·Reduction of wiring between devices by means of crosscommunication via Ethernet (IEC 61850 GOOSE)
·Time synchronization to the millisecond via Ethernet with SNTP for targeted fault evaluation
·Adjustable to the protection requirements by means of "flexible protection functions"
·Comfortable engineering and evaluation via DIGSI 4.

Fig. 2/3 SIPROTEC Compact Fig. 2/4 SIPROTEC Compact rear view

15
2/4 Siemens SIP · Edition No. 8

Fig. 2/5 Feeder protection relay SIPROTEC with HMI

Overview
SIPROTEC Device Series

SIPROTEC 5 the new benchmark for protection, automation and monitoring
The SIPROTEC 5 series is based on the long field experience of the SIPROTEC device series, and has been especially designed for the new requirements of modern high-voltage systems. For this purpose, SIPROTEC 5 is equipped with extensive functionalities and device types. With the holistic and consistent engineering tool DIGSI 5, a solution has also been provided for the increasingly complex processes, from the design via the engineering phase up to the test and operation phase.
Thanks to the high modularity of hardware and software, the functionality of the device types can be tailored to the requested application and adjusted to the ever changing requirements throughout the entire lifecycle.
In addition to the reliable and selective protection and the complete automation function, SIPROTEC 5 offers an extensive database for operation and monitoring of modern power supply systems. Synchrophasors (PMU), power quality data and extensive operational equipment data are part of the scope of supply.
·Powerful protection functions guarantee the safety of the system operator's equipment and employees
·Individually configurable devices save money on initial investment as well as storage of spare parts, maintenance, expansion and adjustment of your equipment
·Arc protection, detection of transient ground faults, and process bus can easily be integrated and retrofitted
·Clear and easy-to-use of devices and software thanks to user-friendly design
·Increase of reliability and quality of the engineering process
·High reliability due to consequent implementation of safety and security
·Powerful communication components guarantee safe and effective solutions
·Full compatibility between IEC 61850 Editions 1 and 2
·Integrated switch for low-cost and redundant optical and electrical Ethernet rings
·Ethernet redundancy protocols RSTP, PRP and HSR for highest availability
·Efficient operating concepts by flexible engineering of IEC 61850 Edition 2
·Comprehensive database for monitoring of modern power grids
·Optimal smart automation platform for transmission grids based on integrated synchrophasor measurement units (PMU) and power quality functions.

Fig. 2/6 SIPROTEC 5 modular hardware Fig. 2/7 SIPROTEC 5 rear view

1 2 3 4 5 6 7 8 9 10 11 12

Fig. 2/8 Application in the high-voltage system

Siemens SIP · Edition No. 8 2/5

Overview
SIPROTEC Device Series

1 2 3 4 5 6 7 8 9 10

SIPROTEC 4 the proven, reliable and future-proof protection for all applications
SIPROTEC 4 represents a worldwide successful and proven device series with more than 1 million devices in field use.
Due to the homogenous system platform, the unique engineering program DIGSI 4 and the great field experience, the SIPROTEC 4 device family has gained the highest appreciation of users all over the world. Today, SIPROTEC 4 is considered the standard for numerical protection systems in all fields of application.
SIPROTEC 4 provides suitable devices for all applications from power generation and transmission up to distribution and industrial systems.
SIPROTEC 4 is a milestone in protection systems. The SIPROTEC 4 device series implements the integration of protection, control, measuring and automation functions optimally in one device. In many fields of application, all tasks of the secondary systems can be performed with one single device. The open and future-proof concept of SIPROTEC 4 has been ensured for the entire device series with the implementation of IEC 61850.
·Proven protection functions guarantee the safety of the systems operator's equipment and employees
·Comfortable engineering and evaluation via DIGSI 4
·Simple creation of automation solutions by means of the integrated CFC
·Targeted and easy operation of devices and software thanks to user-friendly design
·Powerful communication components guarantee safe and effective solutions
·Maximum experience worldwide in the use of SIPROTEC 4 and in the implementation of IEC 61850 projects
·Future-proof due to exchangeable communication interfaces and integrated CFC.
·Integrated switch for low-cost and redundant optical Ethernet rings
·Ethernet redundancy protocols RSTP, PRP and HSR for highest availability.

Fig. 2/9 SIPROTEC 4 Fig. 2/10 SIPROTEC 4 rear view

15
2/6 Siemens SIP · Edition No. 8

Fig. 2/11 SIPROTEC 4 in power plant application

Overview
SIPROTEC Device Series

To fulfill vital protection redundancy requirements, only those

Measuring included

functions that are interdependent and directly associated with each other are integrated into the same unit. For backup protection, one or more additional units should be provided.

For many applications, the accuracy of the protection current transformer is sufficient for operational measuring. The additional measuring current transformer was required to protect

All relays can stand fully alone. Thus, the traditional protection the measuring instruments under short-circuit conditions. Due

principle of separate main and backup protection as well as the external connection to the switchyard remain unchanged.

to the low thermal withstand capability of the measuring instruments, they could not be connected to the protection current

"One feeder, one relay" concept

transformer. Consequently, additional measuring core current transformers and measuring instruments are now only necessary

Analog protection schemes have been engineered and assembled from individual relays. Interwiring between these relays and scheme testing has been carried out manually in the

where high accuracy is required, e.g., for revenue metering. Corrective rather than preventive maintenance

workshop.

Numerical relays monitor their own hardware and software.

Data sharing now allows for the integration of several protection and protection-related tasks into one single numerical relay.

Exhaustive self-monitoring and failure diagnostic routines are not restricted to the protection relay itself but are methodically carried through from current transformer circuits to tripping

Only a few external devices may be required for completion of the total scheme. This has significantly lowered the costs of

relay coils.

engineering, assembly, panel wiring, testing and commissioning. Equipment failures and faults in the current transformer circuits

Scheme failure probability has also been lowered.

are immediately reported and the protection relay is blocked.

Engineering has moved from schematic diagrams toward a

Thus, service personnel are now able to correct the failure upon

parameter definition procedure. The powerful user-definable

occurrence, resulting in a significantly upgraded availability of

logic of SIPROTEC 4 allows flexible customized design for protec- the protection system. tion, control and measurement.

67N

85
to remote line end
21 Distance protection 67N Directional ground-fault protection FL Distance-to-fault locator 79 Auto-reclosure 25 Synchrocheck 85 Carrier interface (teleprotection) SM Self-monitoring ER Event recording FR Fault recording BM Breaker monitor

SIPROTEC Line protection Serial link to station or personal computer

kA,

kV, Hz,

MW,

MVAr,

Load monitor MVA

Fault report

Fault record

Relay monitor Breaker monitor

Supervisory control

Fig. 2/12 Numerical relays offer increased information availability

8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 2/7

Overview
SIPROTEC Device Series

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Adaptive relaying
Numerical relays now offer reliable, convenient and comprehensive matching to changing conditions. Matching may be initiated either by the relay's own intelligence or from other systems via contacts or serial telegrams. Modern numerical relays contain a number of parameter sets that can be pretested during commissioning of the scheme. One set is normally operative. Transfer to the other sets can be controlled via binary inputs or a serial data link (Fig. 2/13).
There are a number of applications for which multiple setting groups can upgrade the scheme performance, for example:
·For use as a voltage-dependent control of overcurrent-time relay pickup values to overcome alternator fault current decrement to below normal load current when the automatic voltage regulator (AVR) is not in automatic operation
·For maintaining short operation times with lower fault currents, e.g., automatic change of settings if one supply transformer is taken out of service
·For "switch-onto-fault" protection to provide shorter time settings when energizing a circuit after maintenance so that normal settings can be restored automatically after a time delay
·For auto-reclosure programs, that is, instantaneous operation for first trip and delayed operation after unsuccessful reclosure
·For cold load pickup problems where high starting currents may cause relay operation
·For "ring open" or "ring closed" operation.

1000
1.. 100 1.. 200 1.. 500 2.. 800 3900

1000 Parameter PLOOia//n11..1..1..2..CCrea12508PEm000d00ha00a000eratttsaheersseePLOOFtttiaatn//i11..1..1..2..3irCCunne125a089lgAgPEt0m00000dshasr000000aeeratttcsaheoerrssdeeOOFBPLitn1..1..1..2..3tairat//nte1CC25uig89rineaan000l00PEBtgkmg00d000hasresaerearttctsfhaeoearrsisldLeueOOFBiitrnnttaret//igeeCCuinnaldgCPEtgkasharesteraratcsfhoearsisldeueitrnttetiginnDggss Fa3u9lt0r0ecordiBnrgeaker failure Breaker failure

Fig. 2/13 Alternate parameter groups

Implemented functions
SIPROTEC relays are available with a variety of protective functions (please refer to Fig. 2/15). The high processing power of modern numerical units allows further integration of nonprotective add-on functions.
The question as to whether separate or combined relays should be used for protection and control cannot be unambiguously answered. In transmission-type substations, separation into independent hardware units is still preferred, whereas a trend toward higher function integration can be observed on the distribution level. Here, the use of combined feeder / line relays for protection, monitoring and control is becoming more common (Fig. 2/14).
Relays with protection functions only and relays with combined protection and control functions are being offered. SIPROTEC 4 relays offer combined protection and control functions. SIPROTEC 4 relays support the "one relay one feeder" principle, and thus contribute to a considerable reduction in space and wiring requirements.
With the well-proven SIPROTEC 4 family, Siemens supports both stand-alone and combined solutions on the basis of a single hardware and software platform. The user can decide within wide limits on the configuration of the control and protection, and the reliability of the protection functions (Fig. 2/15).
The following solutions are available within one relay family:
·Separate control and protection relays
·Feeder protection and remote control of the line circuit-breaker via the serial communication link
·Combined relays for protection, monitoring and control.

Fig. 2/14 Left: switchgear with numerical relay (7SJ62) and traditional control; right: switchgear with combined protection and control relay (7SJ64)

2/8 Siemens SIP · Edition No. 8

Overview
SIPROTEC Device Series

Busbar 52

7SJ61/62/63/64

7SJ62/63/64 2)

Local/remote control Command/feedback

CFC logic Metering values

25 Synchronization

Trip circuit supervision

74TC

Lockout

Set points, mean values, Min/Max-Log

I, V, Watts, Vars, p.f., f

V, f, P

P<> Q<>

p.f.

df/dt

Motor 33 Communication

control

modules

RTD1) box interface

Energy meter: calculated and/or by impulses

55 81R

f<> V> V<

HMI

RS232/485/FO/ Fault

Motor protection

Ethernet

recording

Bearing

Starting

Fault

81O/U 59 27

IEC60870-5-103

temp. I<

time

locator

Directional

IEC61850 Profibus DP DNP 3.0 MODBUS RTU

21FL

phase-sequence 47 monitoring

14 Locked rotor

66/86

Restart inhibit

I dir.>> I dir.> Ipdir.

IIIEEEpdddiiirrr...>>>

I>> I>, Ip 50 51

IE >> IIEEp>, 50N 51N

I2 > > 46 49

Inrush restraint

Interm. earth flt.

IE >> 50N

IIEEp>, 51N

High-impedance

Auto-

restricted ground-fault 79 reclosure

87N

50BF
Breaker failure protection

67 67N

5
Dir. sensitive ground-fault detection

IIIEEEEEEp>>>

VE>

67Ns

1)RTD = resistance temperature detector

2) VT connection for 7SJ62/63/64 only

Fig. 2/15 SIPROTEC 4 relays 7SJ61 / 62 / 63, 64 implemented functions

Terminals: Standard relay version with screw-type terminals

Current terminals Connection Ring cable lugs Wire size Direct connection
Wire size

Wmax =12 mm d1 = 5 mm 2.7 4 mm2 (AWG 13 11)
Solid conductor, flexible lead, connector sleeve 2.7 4 mm2 (AWG 13 11)

Voltage terminals

Connection Ring cable lugs Wire size

Wmax =10 mm d1 = 4 mm 1.0 2.6 mm2 (AWG 17 13)

Direct connection

Solid conductor, flexible lead, connector sleeve

Wire size

0.5 2.5 mm2 (AWG 20 13)

Some relays are alternatively available with plug-in voltage terminals

Current terminals Screw type (see standard version)

Voltage terminals 2-pin or 3-pin connectors Wire size

0.5 1.0 mm2 0.75 1.5 mm2 1.0 2.5 mm2

Mechanical Design
SIPROTEC 4 relays are available in to of 19" wide housings with a standard height of 243 mm. Their size is compatible with that of other device series. Therefore, compatible exchange is always possible (Fig. 2/16 to Fig. 2/18).
All wires (cables) are connected at the rear side of the relay with or without ring cable lugs. A special relay version with a detached cable-connected operator panel (Fig. 2/19) is also available. It allows, for example, the installation of the relay itself in the low-voltage compartment, and of the operator panel separately in the door of the switchgear.

8 9 10 11

15
Siemens SIP · Edition No. 8 2/9

Overview
SIPROTEC Device Series

Fig. 2/16 of 19" housing

7
Fig. 2/17 ½ of 19" housing
8

Fig. 2/18 of 19" housing

On the backlit LCD display, process and device information can
be displayed as text.
Freely assignable LEDs are used to display process or device
information. The LEDs can be labeled according to user requirements. An LED reset key resets the LEDs and can be used for LED testing.
Keys for navigation RS232 operator interface (for DIGSI) 4 configurable function keys permit the user to execute
frequently used actions simply and fast.
Numerical keys
Fig. 2/20 Local operation: All operator actions can be executed and information displayed via an integrated user interface. Two alternatives for this interface are available.

Fig. 2/19 SIPROTEC 4 combined protection, control and monitoring relay with detached operator panel

15
2/10 Siemens SIP · Edition No. 8

Process and relay information can be displayed on the large
illuminated LC display either graphically in the form of a mimic diagram or as text in various lists.
The keys mainly used for control of the switchgear are located
on the "control axis" directly below the display.
Two key-operated switches ensure rapid and reliable changeover
between "local" and "remote" control, and between "interlocked" and "non-interlocked" operation.
Fig. 2/21 Additional features of the interface with graphic display

Overview
SIPROTEC Device Series

Apart from the relay-specific protection functions, the SIPROTEC 4 units have a multitude of additional functions that ·provide the user with information for the evaluation of faults ·facilitate adaptation to customer-specific application ·facilitate monitoring and control of customer installations.

Operational measured values
The large scope of measured and limit values permits improved power system management as well as simplified commissioning.
The r.m.s. values are calculated from the acquired current and voltage along with the power factor, frequency, active and reactive power. The following functions are available depending on the relay type
·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
·Energy ± kWh ± kVarh, forward and reverse power flow
·Mean as well as minimum and maximum current and voltage values
·Operating hours counter
·Mean operating temperature of overload function
·Limit value monitoring Limit values are monitored using programmable logic in the CFC. Commands can be derived from this limit value indication.
·Zero suppression In a certain range of very low measured values, the value is set to zero to suppress interference.

Fig. 2/22 Operational measured values

Metered values (some types)
For internal metering, the unit can calculate energy metered values from the measured current and voltage values. If an external meter with a metering pulse output is available, some SIPROTEC 4 types can obtain and process metering pulses via an indication input.
The metered values can be displayed and passed on to a control center as an accumulation with reset. A distinction is made between forward, reverse, active and reactive energy.

Operational indications and fault indications with time stamp
The SIPROTEC 4 units provide extensive data for fault analysis as well as control. All indications listed here are stored, even if the power supply is disconnected.
·Fault event log The last eight network faults are stored in the unit. All fault recordings are time-stamped with a resolution of 1 ms.
·Operational indications All indications that are not directly associated with a fault (e.g., operating or switching actions) are stored in the status indication buffer. The time resolution is 1 ms (Fig. 2/22, Fig. 2/23).

Fig. 2/23 Fault event log on graphical display of the device

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 2/11

Overview
SIPROTEC Device Series

1 2 3 4 5 6 7 8 9 10 11 12

Display editor
A display editor is available to design the display on SIPROTEC 4 units with graphic display. The predefined symbol sets can be expanded to suit the user. The drawing of a single-line diagram is extremely simple. Load monitoring values (analog values) and any texts or symbols can be placed on the display where required.
Four predefined setting groups for adapting relay settings
The settings of the relays can be adapted quickly to suit changing network configurations. The relays include four setting groups that can be predefined during commissioning or even changed remotely via a DIGSI 4 modem link. The setting groups can be activated via binary inputs, via DIGSI 4 (local or remote), via the integrated keypad or via the serial substation control interface.
Fault recording up to five or more seconds
The sampled values for phase currents, earth (ground) currents, line and zero-sequence currents are registered in a fault record. The record can be started using a binary input, on pickup or when a trip command occurs. Up to eight fault records may be stored. For test purposes, it is possible to start fault recording via DIGSI 4. If the storage capacity is exceeded, the oldest fault record in each case is overwritten.
For protection functions with long delay times in generator protection, the RMS value recording is available. Storage of relevant calculated variables (V1, VE, I1, I2, IEE, P, Q, f-fn) takes place at increments of one cycle. The total time is 80 s.
Time synchronization
A battery-backed clock is a standard component and can be synchronized via a synchronization signal (DCF77, IRIG B via satellite receiver), binary input, system interface or SCADA (e.g., SICAM). A date and time is assigned to every indication.

Reliable battery monitoring
The battery provided is used to back up the clock, the switching statistics, the status and fault indications, and the fault recording in the event of a power supply failure. Its function is checked by the processor at regular intervals. If the capacity of the battery is found to be declining, an alarm is generated. Regular replacement is therefore not necessary.
All setting parameters are stored in the Flash EPROM and are not lost if the power supply or battery fails. The SIPROTEC 4 unit remains fully functional.
Commissioning support
Special attention has been paid to commissioning. All binary inputs and output contacts can be displayed and activated directly. This can significantly simplify the wiring check for the user. Test telegrams to a substation control system can be initiated by the user as well.
CFC: Programming logic
With the help of the CFC (Continuous Function Chart) graphic tool, interlocking schemes and switching sequences can be configured simply via drag and drop of logic symbols; no special knowledge of programming is required. Logical elements, such as AND, OR, flip-flops and timer elements are available. The user can also generate user-defined annunciations and logical combinations of internal or external signals.
Communication interfaces
With respect to communication, particular emphasis has been placed on high levels of flexibility, data integrity and utilization of standards commonly used in energy automation. The design of the communication modules permits interchangeability on the one hand, and on the other hand provides openness for future standards.

Selectable function keys
Four function keys can be assigned to permit the user to perform frequently recurring actions very quickly and simply.
Typical applications are, for example, to display the list of operating indications or to perform automatic functions such as "switching of circuit-breaker".

Local PC interface
The PC interface accessible from the front of the unit permits quick access to all parameters and fault event data. Of particular advantage is the use of the DIGSI 4 operating program during commissioning.

Continuous self-monitoring
The hardware and software are continuously monitored. If abnormal conditions are detected, the unit immediately signals. In this way, a great degree of safety, reliability and availability is achieved.

15
2/12 Siemens SIP · Edition No. 8

Overview
SIPROTEC Device Series

Retrofitting: Communication modules
It is possible to supply the relays directly with two communication modules for the service and substation control interfaces, or to retrofit the communication modules at a later stage. The modules are mounted on the rear side of the relay. As a standard, the time synchronization interface is always supplied.
The communication modules are available for the entire SIPROTEC 4 relay range. Depending on the relay type, the following protocols are available: IEC 60870-5-103, PROFIBUS DP, PROFINET I/O, MODBUS RTU, DNP 3.0 and Ethernet with IEC 61850. No external protocol converter is required.
With respect to communication, particular emphasis is placed on the requirements in energy automation:
·Every data item is time-stamped at the source, that is, where it originates.
·The communication system automatically handles the transfer of large data blocks (e.g., fault records or parameter data files). The user can apply these features without any additional programming effort.
·For reliable execution of a command, the relevant signal is first acknowledged in the unit involved. When the command has been enabled and executed, a check-back indication is issued. The actual conditions are checked at every command-handling step. Whenever they are not satisfactory, controlled interruption is possible.

Fig. 2/24 Protection relay

Fig. 2/25 Communication module, optical

The following interfaces can be applied:
Service interface (optional)
Several protection relays can be centrally operated with DIGSI 4, e.g., via a star coupler or RS485 bus. On connection of a modem, remote control is possible. This provides advantages in fault clearance, particularly in unmanned power stations. (Alternatively, the external temperature monitoring box can be connected to this interface.)
System interface (optional)
This is used to carry out communication with a control system and supports, depending on the module connected, a variety of communication protocols and interface designs.
Time synchronization interface
A synchronization signal (DCF 77, IRIG B via satellite receiver) may be connected to this input if no time synchronization is executed on the system interface. This offers a high-precision time tagging.
Fig. 2/28 Rear view with wiring, terminal safety cover and serial interfaces

1 2 3 4 5 6 7 8 9 10 11 12

Fig. 2/26 Communication module RS232,RS485

Fig. 2/27 Communication module, optical ring

13 14

15
Siemens SIP · Edition No. 8 2/13

Overview
SIPROTEC Device Series

1 2 3 4 5 6 7 8 9 10

Safe bus architecture
·Fiber-optic double ring circuit via Ethernet The fiber-optic double ring circuit is immune to electromagnetic interference. Upon failure of a section between two units, the communication system continues to operate without interruption. If a unit were to fail, there is no effect on the communication with the rest of the system (Fig. 2/29).
·RS485 bus With this data transmission via copper wires, electromagnetic interference is largely eliminated by the use of twisted-pair conductors. Upon failure of a unit, the remaining system continues to operate without any faults (Fig. 2/30).
·Star structure The relays are connected with a fiber-optic cable with a star structure to the control unit. The failure of one relay / connection does not affect the others (Fig. 2/31).
Depending on the relay type, the following protocols are available:
·IEC 61850 protocol Since 2004, the Ethernet-based IEC 61850 protocol is the worldwide standard for protection and control systems used by power supply corporations. Siemens is the first manufacturer to support this standard. By means of this protocol, information can also be exchanged directly between feeder units so as to set up simple masterless systems for feeder and system interlocking. Access to the units via the Ethernet bus will also be possible with DIGSI.
·IEC 60870-5-103 IEC 60870-5-103 is an internationally standardized protocol for efficient communication between the protection relays and a substation control system. Specific extensions that are published by Siemens can be used.
·PROFIBUS DP For connection to a SIMATIC PLC, the PROFIBUS DP protocol is recommended. With the PROFIBUS DP, the protection relay can be directly connected to a SIMATIC S5 / S7. The transferred data are fault data, measured values and control commands.

Substation automation system

DIGSI

Option: SICAM
PAS

Control center

switch

Fig. 2/29 Ring bus structure for station bus with Ethernet and IEC 61850
Substation control system

Fig. 2/30 PROFIBUS: Electrical RS485 bus wiring

11 12

Substation control system

14 15
2/14 Siemens SIP · Edition No. 8

Fig. 2/31 IEC 60870-5-103: Star structure with fiber-optic cables

Overview
SIPROTEC Device Series

MODBUS RTU

MODBUS is also a widely utilized communication standard and is used in numerous automation solutions.

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 2-compliant with DNP 3.0, which is supported by a number of protection unit manufacturers.

Control

In addition to the protection functions, the SIPROTEC 4 units also support all control and monitoring functions required for operating medium-voltage or high-voltage substations. The main application is reliable control of switching and other processes. The status of primary equipment or auxiliary devices can be obtained from auxiliary contacts and communicated to the relay via binary inputs.

Fig. 2/32 Protection engineer at work

Therefore, it is possible to detect and indicate both the OPEN and CLOSED positions or a faulty or intermediate breaker position. The switchgear can be controlled via: ·Integrated operator panel ·Binary inputs ·Substation control system ·DIGSI 4
Automation

Switching authority
The following hierarchy of switching authority is applicable: LOCAL, DIGSI 4 PC program, REMOTE. The switching authority is determined according to parameters or by DIGSI 4. If the LOCAL mode is selected, only local switching operations are possible. Every switching operation and change of breaker position is stored in the status indication memory with detailed information and time tag.

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

Command processing
The SIPROTEC 4 protection relays offer all functions required for command processing, including the processing of single and double commands, with or without feedback, and sophisticated monitoring. Control actions using functions, such as runtime monitoring and automatic command termination after output check of the external process, are also provided by the relays. Typical applications are:
·Single and double commands using 1, 1 plus 1 common or 2 trip contacts
·User-definable feeder interlocking
·Operating sequences combining several switching operations, such as control of circuit-breakers, disconnectors (isolators) and grounding switches
·Triggering of switching operations, indications or alarms by logical combination of existing information (Fig. 2/32).

The positions of the circuit-breaker or switching devices are monitored by feedback signals. These indication inputs are logically assigned to the corresponding command outputs. The unit can therefore distinguish whether the indication changes as a consequence of a switching operation or due to a spontaneous change of state.

2 3 4 5 6 7 8 9 10 11 12 13 14

Siemens SIP · Edition No. 8 2/15

Overview
Typical protection schemes

Typical protection schemes

1. Cables and overhead lines

Radial systems

Infeed

Transformer protection see fig. 2/49

2 Notes: 1) Auto-reclosure (ANSI 79) only with overhead lines.

2) Negative sequence overcurrent protection 46 as sensitive

backup protection against asymmetrical faults.

General notes:

·The relay at the far end (D) is set with the shortest operating

time. Relays further upstream have to be time-graded against

the next downstream relay in steps of about 0.3 s.

·Inverse time or definite time can be selected according to the

following criteria:

A B Further feeders C
Load

I>, t IE >, t I2 >, t ARC 51 51N 46 79

7SJ80*)

2) 1)

I>, t IE >, t I2 >, t 51 51N 46 7SJ80*)

Definite time: Source impedance is large compared to the line impedance,

that is, there is small current variation between near and far

end faults.

I>, t IE >, t I2 >, t

51 51N 46

7SJ80*)

Inverse time: Longer lines, where the fault current is much less at the far

end of the line than at the local end.

Load

Load *) Alternatives: 7SJ82, 7SJ66

Strong or extreme inverse-time:

Lines where the line impedance is large compared to the source impedance (high difference for close-in and remote

Fig. 2/33 Radial systems

faults), or lines where coordination with fuses or reclosers is

necessary. Steeper characteristics also provide higher stabil-

ity on service restoration (cold load pickup and transformer

inrush currents).

9 10 11

Ring-main circuit
General notes: ·Operating time of overcurrent relays to be coordinated with
downstream fuses of load transformers (preferably with strong inverse-time characteristic with about 0.2 s grading-time delay) ·Thermal overload protection for the cables (option) ·Negative sequence overcurrent protection (46) as sensitive protection against asymmetrical faults (option).

Infeed

Transformer protection see fig. 2/52

52
7SJ80*) I>, t IE >, t I2 >, t >
51 51N 46 49

14 15
2/16 Siemens SIP · Edition No. 8

Fig. 2/34 Ring-main circuit

*) Alternatives: 7SJ82, 7SJ66

Overview
Typical protection schemes

Switch-onto-fault protection
If switched onto a fault, instantaneous tripping can be effected. If the internal control function is used (local, via binary input or via serial interface), the manual closing function is available without any additional wiring. If the control switch is connected to a circuit-breaker bypassing the internal control function, manual detection using a binary input is implemented.

52 Busbar

TRIP (high-speed dead fault clearance) (511)

I>>, I>>>

Feeder earthed

Typical feeder

Manual close (356 > m close)

7SJx, 7SAx

Fig. 2/35 Switch-onto-fault protection

Directional comparison protection (cross-coupling)
Cross-coupling is used for selective protection of sections fed from two sources with instantaneous tripping, that is, without the disadvantage of time coordination. The directional comparison protection is suitable if the distances between the protection stations are not significant and pilot wires are available for signal transmission. In addition to the directional comparison protection, the directional coordinated overcurrent-time protection is used for complete selective backup protection. If operated in a closed-circuit connection, an interruption of the transmission line is detected.

Substation A Bus 52

Substation B 52 Bus 52

Substation C 52 Bus 52

Substation D 52 Bus

7SJ62/ 63/64
50

Blocking bus

52
50 7SJ80 Pickup
52
50 7SJ80 Pickup

Blocking signal Non-directional 50 fault detection Direction of fault (67)

Fig. 2/36 Directional comparison protection

Distribution feeder with reclosers
General notes:
·The feeder relay operating characteristics, delay times and auto-reclosure cycles must be carefully coordinated with downstream reclosers, sectionalizers and fuses. The 50 / 50N instantaneous zone is normally set to reach out to the first main feeder sectionalizing point. It has to ensure fast clearing of close-in faults and prevent blowing of fuses in this area ("fuse saving"). Fast auto-reclosure is initiated in this case. Further time-delayed tripping and reclosure steps (normally two or three) have to be graded against the recloser.
·The overcurrent relay should automatically switch over to less sensitive characteristics after long breaker interruption times in order to enable overriding of subsequent cold load pickup and transformer inrush currents.

Infeed

I>>, IE >>, I2 >, t 7SJ61

I>, t IE >, t

7SJ80

50/51 50N/51N 46

Recloser

79 Autoreclose

52
Further feeders

Sectionalizers

1 2 3 4 5 6 7 8 9 10 11 12 13

Fuses

Fig. 2/37 Distribution feeder with reclosers

Siemens SIP · Edition No. 8 2/17

Overview
Typical protection schemes

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

Auto-reclosure (AR) enables 3-phase auto-reclosing of a feeder that has previously been disconnected by overcurrent protection.

SIPROTEC 7SJ61 allows up to nine reclosing shots. The first four

dead times can be set individually. Reclosing can be blocked or

initiated by a binary input or internally. After the first trip in a

reclosing sequence, the high-set instantaneous elements (I>>>,

I>>, IE>>) can be blocked. This is used for fuse-saving applications and other similar transient schemes using simple overcurrent

relays instead of fuses. The low-set definite-time (I>, IE>) and the inverse-time (Ip, IEp) overcurrent elements remain operative during

the entire sequence.

Elements can Elements

be blocked are slower

than the

fuse

52 (2851)

Performs reclosure of feeder

TRIP (511)

50N

51N

7SJ61*)
AR 79

Fuse opens on

sucessful reclosure

Circuit-breaker opens on unsucessful reclosure
51
*) Alternatives: 7SJ62/63/64/66, 7SJ80/82/85

7 8 9 10 11

Parallel feeder circuit
General notes:
·The preferred application of this circuit is in the reliable supply of important consumers without significant infeed from the load side.
·The 67 / 67N directional overcurrent protection trips instantaneously for faults on the protected line. This saves one time-grading interval for the overcurrent relays at the infeed.
·The 51 / 51N overcurrent relay functions must be time-graded against the relays located upstream.

Fig. 2/38 3-pole multishot auto-reclosure (AR, ANSI 79)

Infeed

I>, t IE >, t > I2 >, t
51 51N 49 46
O H line or cable 1
67 67N 51 51N
52

7SJ61 7SJ80 7SJ82
O H line or cable 2
7SJ62 7SJ80 7SJ82

Protection same as line or cable 1
52

12 13

Load Fig. 2/39 Parallel feeder circuit

Load

15
2/18 Siemens SIP · Edition No. 8

Reverse-power monitoring at double infeed
If a busbar is fed from two parallel infeeds and a fault occurs on one of them, only the faulty infeed should be tripped selectively in order to enable supply to the busbar to continue from the remaining supply. Unidirectional devices that can detect a short-circuit current or energy flow from the busbar toward the incoming feeder should be used. Directional overcurrent protection is usually set via the load current. However, it cannot clear weak-current faults. The reverse-power protection can be set much lower than the rated power, thus also detecting the reverse-power flow of weak-current faults with fault currents significantly below the load current.

Overview
Typical protection schemes

Infeed A

Infeed B

67 67N

32R

7SJ64 *) 52

7SJ64 *)

Feeders *) Alternatives: 7SJ62, 7SJ80, 7SJ66, 7SJ82 Feeders

Fig. 2/40 Reverse-power monitoring at double infeed

Synchronization function
Note:
Also available in relays 7SA6, 7SD5, 7SA522, 7VK61.
General notes: ·When two subsystems must be interconnected, the synchroni-
zation function monitors whether the subsystems are synchronous and can be connected without risk of losing stability. ·This synchronization function can be applied in conjunction with the auto-reclosure function as well as with the control function CLOSE commands (local / remote).

52 CLOSE command

Transformer

Infeed

3 U1

1) 25 SYN

Busbar
Local/remote control
79 AR 7SJ641)

Fig. 2/41 Synchronization function

6 7 8 9 10 11

15
Siemens SIP · Edition No. 8 2/19

Overview
Typical protection schemes

Cables or short overhead lines with infeed from both ends

1 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 a 64 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 7SD80 with pilot wire and/or fibre optic protection data

interface.

Infeed 52
52

Line or cable

52 7SJ80
51N/51N
7SJ80 51N/51N
52

79 1)

7SD61,

87L

7SD80 or 7SD5

87L

7SD61,

79 1)

7SD80 or 7SD5

52
Same protection for parallel line, if applicable
52

Load

Backfeed

Fig. 2/42 Cables or short overhead lines with infeed from both ends

Overhead lines or longer cables with infeed from both ends

6 Notes:

1) Teleprotection logic (85) for transfer trip or blocking schemes.

Signal transmission via pilot wire, power line carrier, digital

network or optical fiber (to be provided separately). The teleprotection supplement is only necessary if fast fault clearance

on 100 % line length is required, that is, second zone tripping

(about 0.3 s delay) cannot be accepted for far end faults. For

further application notes on teleprotection schemes, refer to

the table on the following page.

2) Directional ground-fault protection 67N with inverse-time delay against high-resistance faults

3) Single or multishot auto-reclosure (79) only with overhead lines.

Infeed 52
52
52

Line or cable

21N/21N 85

67N 22))

7SA6 or 7SA522

79 3)

21N/21N

67N

7SA6 or 7SA522

Same protection for parallel line, if applicable

Load

Backfeed

Fig. 2/43 Overhead lines or longer cables with infeed from both ends

11 12 13 14 15

Subtransmission line
Note:
Connection to open delta winding if available. Relays 7SA6 / 522 and 7SJ62 can, however, also be set to calculate the zerosequence voltage internally.
General notes: ·Distance teleprotection is proposed as main protection and
time-graded directional overcurrent as backup protection. ·The 67N function of 7SA6 / 522 provides additional high-
resistance ground-fault protection. It can be used in parallel with the 21 / 21N function. ·Recommended teleprotection schemes: PUTT on medium and long lines with phase shift carrier or other secure communication channel POTT on short lines. BLOCKING with On / Off carrier (all line lengths).

25 79 21N/21N

68/78

67N

85 7SA6 or 7SA522

67/67N

51/51N

7SJ62 7SJ80

S CH
R

To remote line end

Signal transmission equipment

Fig. 2/44 Subtransmission line

2/20 Siemens SIP · Edition No. 8

Overview
Typical protection schemes

Preferred application
Advantages
Drawbacks

Signal transmission system
Characteristic of line

Permissive underreach transfer trip (PUTT)

Permissive overreach transfer trip (POTT)

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 avoid transmission of the HF signal through the fault location. · Microwave radio, especially digital (PCM) · Fiber-optic cables

Best suited for longer lines where the underreach zone provides sufficient resistance coverage
· Simple technique · No coordination of zones
and times with the opposite end required. The combination of different relay types therefore presents no problems
· Overlapping of the zone 1 reaches must be ensured. On parallel lines, teed feeders and tapped lines, the influence of zero sequence coupling and intermediate infeeds must be carefully considered to make sure a minimum overlapping of the zone 1 reach is always present.
· Not suitable for weak infeed terminals

· Excellent coverage on short lines in the presence of fault resistance.
· Suitable for the protection of multi-terminal lines with intermediate infeed
· Can be applied without underreaching zone 1 stage (e.g., overcompensated series uncompensated lines)
· Can be applied on extremely short lines (impedance less than minimum relay setting)
· Better for parallel lines as mutual coupling is not critical for the overreach zone
· Weak infeed terminals are no problem (Echo and Weak Infeed logic is included)
· Zone reach and signal timing coordination with the remote end is necessary (current reversal)

Blocking
Reliable communication channel (only required during external faults) · Power line carrier with
amplitude modulation (ON / OFF). The same frequency may be used on all terminals) All line types preferred practice in the US
Same as POTT
Same as POTT · Slow tripping all
teleprotection trips must be delayed to wait for the eventual blocking signal · Continuous channel monitoring is not possible

Unblocking Dedicated channel with continuous signal transfer · Power line carrier with
frequency shift keying. Continuous signal transmission must be permitted.
Same as POTT
Same as POTT but: · If no signal is received
(no block and no uncompensated block) then tripping by the overreach zone is released after 20 ms
Same as POTT

Table 2/1 Application criteria for frequently used teleprotection schemes

1 2 3 4 5 6 7 8 9 10 11

15
Siemens SIP · Edition No. 8 2/21

Overview
Typical protection schemes

Transmission line with reactor (Fig. 2/45)

Teleprotection schemes based on distance relays therefore

1 Notes: 1) 51N only applicable with grounded reactor neutral.

have operating times on the order of 25 to 30 ms with digital PCM coded communication. With state-of-the-art two-cycle circuit-breakers, fault clearing times well below 100 ms

(4 to 5 cycles) can normally be achieved.

2) If phase CTs at the low-voltage reactor side are not available,

the high-voltage phase CTs and the CT in the neutral can be connected to a restricted ground-fault protection using a

·Dissimilar carrier schemes are recommended for main 1 and main 2 protection, for example, PUTT, and POTT or

high-impedance relay (SIPROTEC 7SJ80, Reyrolle 7SR23).

Blocking / Unblocking.

·Both 7SA522 and 7SA6 provide selective 1-pole and / or 3-pole

General notes:

tripping and auto-reclosure.

·Distance relays are proposed as main 1 and main 2 protection.

The ground-current directional comparison protection (67N)

Duplicated 7SA6 is recommended for series-compensated

of the 7SA6 relay uses phase selectors based on symmetrical

lines.

components. Thus, 1-pole auto-reclosure can also be executed

·Operating time of the distance relays is in the range of 15 to

25 ms depending on the particular fault condition. These tripping times are valid for faults in the underreaching

with high-resistance faults. The 67N function of the 7SA522 relay can also be used as time-delayed directional overcurrent backup.

distance zone (80 to 85 % of the line length). Remote end

·The 67N functions are provided as high-impedance fault

faults must be cleared by the superimposed teleprotection

protection. 67N is often used with an additional channel as

scheme. Its overall operating time depends on the signal transmission time of the channel, typically 15 to 20 ms for

a separate carrier scheme. Use of a common channel with distance protection is only possible if the mode is compatible

frequency shift audio-tone PLC or microwave channels, and

(e.g., POTT with directional comparison). The 67N may be

lower than 10 ms for ON / OFF PLC or digital PCM signaling via

blocked when function 21 / 21N picks up. Alternatively, it can

optical fibers.

be used as time-delayed backup protection.

52L

TC1 TC2
8

9 10 11 12

25 59 21/21N

21/21N

67N

68/79 85

BF 7SA6

68/79

7SA522

Fig. 2/45 Transmission line with reactor

52R
CVT 50/50N 51/51N BF 7SJ80

BF, 59
Trip 52L

Reactor

87R

51N
BF
S Direct trip R channel

S Channel

7SR23 2)
7SJ80 1)
To remote line end

15
2/22 Siemens SIP · Edition No. 8

Overview
Typical protection schemes

Transmission line or cable (with wide-band communication)
General notes:
·Digital PCM-coded communication (with n × 64 kbit / s channels) between line ends is becoming more and more frequently available, either directly by optical or microwave point-to-point links, or via a general-purpose digital communication network. In both cases, the relay-type current differential protection 7SD52 / 61 can be applied. It provides absolute phase and zone selectivity by phase-segregated measurement, and is not affected by power swing or parallel line zero-sequence coupling effects. It is, furthermore, a current-only protection that does not need a VT connection. For this reason, the adverse effects of CVT transients are not applicable. This makes it particularly suitable for double and multi-circuit lines where complex fault situations can occur. The 7SD5 / 61 can be applied to lines up to about 120 km in direct relay-to-relay connections via dedicated optical fiber cores (see also application "Cables or short overhead lines with infeed from both ends", page 2/21), and also to much longer distances of up to about 120 km by using separate PCM devices for optical fiber or microwave transmission. The 7SD5 / 61 then uses only a small part (64 to 512 kbit / s) of the total transmission capacity (on the order of Mbits / s).
·The 7SD52 / 61 protection relays can be combined with the distance relay 7SA52 or 7SA6 to form a redundant protection system with dissimilar measuring principles complementing each other (Fig. 2/46). This provides the highest degree of availability. Also, separate signal transmission ways should be used for main 1 and main 2 line protection, e.g., optical fiber or microwave, and power line carrier (PLC). The current comparison protection has a typical operating time of 15 ms for faults on 100 % line length, including signaling time.
General notes for Fig. 2/47:
·SIPROTEC 7SD5 offers fully redundant differential and distance relays accommodated in one single bay control unit, and provides both high-speed operation of relays and excellent fault coverage, even under complicated conditions. Precise distance-to-fault location avoids time-consuming line patrolling, and reduces the downtime of the line to a minimum.
·The high-speed distance relay operates fully independently from the differential relay. Backup zones provide remote backup for upstream and downstream lines and other power system components.

CC 52L TC1 TC2

87L

59 21/21N

67N

7SD522 7SD6

68/79 85

BF 7SA522 or 7SA6

S Channel R1

Optical fiber FO

X.21 S PCM

Wire

Direct connection with dedicated fibers up to about 120 km

Fig. 2/46 Redundant transmission line protection

CC 52L TC1 TC2

87L

25 59 21/21N
67N

7SD5

85 68/79

S Channel R1

Optical fiber

FO Wire

X.21

S R

PCM

Direct connection with dedicated fibers up to about 120 km

To remote line end
To remote line end

Fig. 2/47 Transmission line protection with redundant algorithm in one device

1 2 3 4 5 6 7 8 9 10 11 12 13

15
Siemens SIP · Edition No. 8 2/23

Overview
Typical protection schemes

1 2 3 4 5 6 7 8 9 10 11

Transmission line, one-breaker-and-a-half terminal
Notes:
1) When the line is switched off and the line line disconnector (isolator) is open, high through-fault currents in the diameter may cause maloperation of the distance relay due to unequal CT errors (saturation). Normal practice is therefore to block the distance protection (21 / 21N) and the directional ground-fault protection (67N) under this condition via an auxiliary contact of the line line disconnector (isolator). A standby overcurrent function (50 / 51N, 51 / 51N) is released instead to protect the remaining stub between the breakers ("stub" protection).

UBB1

87/BB1 7SS52
7VK61 BF 79 52 25

BB1

7SA522 or

7SA6

1) 2)

21/21N 67N 50/50N 51/51N 59

UBB1 UL1 or UL2 or

UL1

UBB2

7VK61 BF

7SD5 87L

Line 1

8/
Line 2

2) Overvoltage protection only with 7SA6 / 52.
General notes:
·The protection functions of one diameter of a breaker-and-a-half arrangement are shown.
·The currents of two CTs have each to be summed up to get the relevant line currents as input for main 1 and 2 line protection.

UBB2

Main 1 Main 2

Protection of line 2 (or transformer, if applicable)

BF 7VK61

UULL12oorrUBB1 UBB2

BB2

87/BB2 7SS52

·The location of the CTs on both sides of the circuit-breakers is typical for substations with dead-tank circuit-breakers.

Fig. 2/48 Transmission line, one-breaker-and-a-half terminal, using 3 breaker management relays 7VK61

Live-tank circuit-breakers may have

CTs only on one side to reduce cost. A fault between circuit-

breakers and CT (end fault) may then still be fed from one side

even when the circuit-breaker has opened. Consequently, final

fault clearing by cascaded tripping has to be accepted in this

case.

·The 7VK61 relay provides the necessary end fault protection function and trips the circuit-breakers of the remaining infeeding circuits.

15
2/24 Siemens SIP · Edition No. 8

Overview
Typical protection schemes

General notes for Fig. 2/48 and Fig. 2/49:

·For the selection of the main 1 and main 2 line protection schemes, the

87/BB1 7SS52

BB1

comments of application examples

7SA522 or

"Transmission with reactor", page 2/23 and "Transmission line or cable", page 2/24 apply.
·Auto-reclosure (79) and synchrocheck

UBB1
52

7SA6

1) 2)

21/21N 67N 50/50N 51/51N 59

function (25) are each assigned directly

to the circuit-breakers and controlled by main 1 and 2 line protection in parallel. In the event of a line fault, both adja-

UBB1 UL1 or UL2 or UBB2 UL1

cent circuit-breakers have to be tripped by the line protection. The sequence of auto-reclosure of both circuit-breakers or, alternatively, the auto-reclosure of

Line 1

7VK61

7SD5

87L

only one circuit-breaker and the manual

closure of the other circuit-breaker, may

be made selectable by a control switch.
·A coordinated scheme of control circuits is necessary to ensure selective

UBUBL11 oUrBUB2L2 or

tripping interlocking and reclosing of the two circuit-breakers of one line (or transformer feeder).

Line 2

UL2

·The voltages for synchrocheck have to

be selected according to the circuit-

Main 1 Protection of Line 2 (or transformer,

breaker and disconnector (isolator) position by a voltage replica circuit.

Main 2 if applicable)

UBB2

General notes for Fig. 2/49:

·In this optimized application, the 7VK61 is only used for the center breaker. In the line feeders, functions 25, 79 and

87/BB2 7SS52

BB2
8

BF are also performed by transmission

line protection 7SA522 or 7SA6.

Fig. 2/49 Transmission line, breaker-and-a-half terminal,

using 1 breaker management relay 7VK61

15
Siemens SIP · Edition No. 8 2/25

Overview
Typical protection schemes

2. Transformers

Small transformer infeed

General notes:

·Ground faults on the secondary side are detected by current

relay 51N. However, it has to be time-graded against downstream feeder protection relays.

·The restricted ground-fault relay 87N can optionally be applied

to achieve fast clearance of ground faults in the transformer

secondary winding. SIPROTEC 7SJ80 is of the high-impedance type and requires

class × CTs with equal transformation ratios.

·Primary circuit-breaker and relay may be replaced by fuses.

HV infeed 52

I>> I>, t IE > > I2 >, t
50 51 50N 49 46 7SJ80

Optional resistor

or reactor RN

I >> 87N 52 7SJ80
52

51N

IE >

7SJ80

Distribution bus

O/C

Fuse

relay

Load

Fig. 2/50 Small transformer infeed

8 9 10 11

Large or important transformer infeed
General note: ·Relay 7UT612 provides numerical ratio and vector group
adaptation. Matching transformers as used with traditional relays are therefore no longer applicable.
Notes:
1) If an independent high-impedance-type ground-fault function is required, the 7SJ6x or 7SJ80 can be used instead of the 87N inside the 7UT612. However, class × CT cores would also be necessary in this case (see small transformer protection).
2) 51 and 51N may be provided in a separate 7SJ80 or 7SJ61 if required.

HV infeed 52
I>> I>, t IE > > I2 >, t 50 51 51N 49 46

7SJ61 or 7SJ80

63 52

51N 87N
2) 2) 51 51N I>, t IE >, t

1) 87T
7UT612

Load bus

Load

Fig. 2/51 Large or important transformer infeed

15
2/26 Siemens SIP · Edition No. 8

Overview
Typical protection schemes

Dual infeed with single transformer General notes: ·Line CTs are to be connected to separate stabilizing inputs of
the differential relay 87T in order to ensure stability in the event of line through-fault currents. ·Relay 7UT613 provides numerical ratio and vector group adaptation. Matching transformers, as used with traditional relays, are therefore no longer applicable.
Parallel incoming transformer feeders Note: The directional functions 67 and 67N do not apply for cases where the transformers are equipped with the transformer differential relays 87T.

Protection line 1 same as line 2
52

Protection line 2 21/21N or 87L + 51 + optionally 67/67N
52

63
52 Load

I>> I>, t IE >, t > I2 > 50 51 51N 49 46
7SJ61 or 7SJ80

51N 7SJ80

I>> IE > 51 51N
52

7SJ80

87N 87T 7UT613

Load

bus

Load

Fig. 2/52 Dual infeed with single transformer

HV infeed 1

52 I>> 50

I>, t IE >, t > I2 >, t 51 51N 49 46
7SJ61 or 7SJ80

I>, t 51
52 1)

IE >, t 51N
51N IE >, t

I> IE > 67 67N
7SJ62 7SJ80

HV infeed 2 52
Protection same as infeed 1
52

Load

bus

Load

Fig. 2/53 Parallel incoming transformer feeders

Parallel incoming transformer feeders with bus tie
General notes: ·Overcurrent relay 51, 51N each connected as a partial differ-
ential scheme. This provides simple and fast busbar protection and saves one time-grading step.

Infeed 1

I>> I>, t IE > t > I2 >, t 50 51 51N 49 46
7SJ80

51N 7SJ80

I>, t IE >, t 51 51N 7SJ80

IE >, t I2>, t 51N 51
7SJ80

52 52
52

Load

Infeed 2 Protection same as infeed 1
52 52 Load

Fig. 2/54 Parallel incoming transformer feeders with bus tie

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 2/27

Overview
Typical protection schemes

1 2 3 4 5 6 7 8 9 10 11 12 13

Three-winding transformer
Notes:
1) The zero-sequence current must be blocked before entering the differential relay with a delta winding in the CT connection on the transformer side with grounded starpoint. This is to avoid false operation during external ground faults (numerical relays provide this function by calculation). About 30 % sensitivity, however, is then lost in the event of internal faults. Optionally, the zero-sequence current can be regained by introducing the winding neutral current in the differential relay (87T). Relay type 7UT613 provides two current inputs for this purpose. By using this feature, the ground-fault sensitivity can be upgraded again to its original value. Restricted ground-fault protection (87T) is optional. It provides backup protection for ground faults and increased ground-fault sensitivity (about 10 % IN, compared to about 20 to 30 % IN of the transformer differential relay). Separate class × CT-cores with equal transmission ratio are also required for this protection.
2) High impedance and overcurrent in one 7SJ61.
General notes:
·In this example, the transformer feeds two different distribution systems with cogeneration. Restraining differential relay inputs are therefore provided at each transformer side.
·If both distribution systems only consume load and no through-feed is possible from one MV system to the other, parallel connection of the CTs of the two MV transformer windings is admissible, which allows the use of a two-winding differential relay (7UT612)

HV Infeed

52 I>>, I >, t > I2 >, t 50 51 49 46 7SJ61 or 7SJ80

51N 7SJ80

1) 87T 7UT613

87N 7SR232)

I>, t IE >, t 51 51N

87Nor

7SJ61 7SJ80

M.V. 52

I>, t IE >, t 51 51N
7SJ802) M.V.
52

Load

Backfeed Load

Fig. 2/55 Three-winding transformer

Backfeed

Autotransformer
Notes:
1) 87N high-impedance protection requires special class × current transformer cores with equal transformation ratios.
2) The 7SJ80 relay can alternatively be connected in series with the 7UT613 relay to save this CT core.
General note: ·Two different protection schemes are provided: 87T is chosen
as the low-impedance three-winding version (7UT613). 87N is a 1-phase high-impedance relay (Reyrolle 7SR23) connected as restricted ground-fault protection. (In this example, it is assumed that the phase ends of the transformer winding are not accessible on the neutral side, that is, there exists a CT only in the neutral grounding connection.).

51N 50/BF 46 50/51 7SJ61 or 7SJ80

2) 1)

87T 49
63 7UT613 52

50/BF

59N

7RW80 7SJ80*)

87N 7SR23 52

50/51

50/BF

51N 7SJ80*) *) Alternatives: 7SJ61

Fig. 2/56 Autotransformer

15
2/28 Siemens SIP · Edition No. 8

Overview
Typical protection schemes

Large autotransformer bank

General notes: ·The transformer bank is connected in a breaker-and-a-half

7SV600

21 21N 68/78 7SA52/6

7SV600

arrangement.

50/BF 52

Duplicated differential protection is proposed:

EHV

·Main 1: Low-impedance differential protection 87TL (7UT613)

connected to the transformer bushing CTs.

·Main 2: High-impedance differential overall protection 87TL (Reyrolle 7SR23). Separate class × cores and equal CT ratios are required for this type of protection.
·Backup protection is provided by distance protection relay (7SA52 and 7SA6), each "looking" with an instantaneous first zone about 80 % into the transformer and with a time-delayed zone beyond the transformer.
·The tertiary winding is assumed to feed a small station supply system with isolated neutral.

3x 87/TH

50/BF 7SV600

7SR23

87/TL 49

7SA52/6

7UT613

21N

68/78

51 52

59N 50/BF 7RW80 7SJ80*)

51N 7SJ80*)

50/BF 7SV600

*) Alternatives: 7SJ61

Fig. 2/57 Large autotransformer bank

3. Motors
Small and medium-sized motors < about 1 MW
a) With effective or low-resistance grounded infeed (IE IN Motor) General note: ·Applicable to low-voltage motors and high-voltage motors
with low-resistance grounded infeed (IE IN Motor) b) With high-resistance grounded infeed (IE IN Motor) Notes:
1) Core-balance CT.
2) Sensitive directional ground-fault protection (67N) only applicable with infeed from isolated or Petersen coil grounded system (for dimensioning of the sensitive directional groundfault protection, see also application circuit page 2/33 and Fig. 2/66)
3) The 7SK80 relay can be applied for isolated and compensated systems.

I>>

IE >

51N

I2 >

7SJ61/7SK80

Fig. 2/58 Motor protection with effective or low-resistance grounded infeed

52 I >> >

I2 > I <

50 49 48 46 37 51U

7XR96 1) 60/1A

IE > 2) 51N 67N

3) 7SJ62/7SK80

Fig. 2/59 Motor protection with high-resistance grounded infeed

7 8 9 10 11 12 13 14

15
Siemens SIP · Edition No. 8 2/29

Overview
Typical protection schemes

Large HV motors > about 1 MW

1 Notes: 1) Core-balance CT.

2) Sensitive directional ground-fault protection (67N) only

applicable with infeed from isolated or Petersen coil grounded system.

3) This function is only needed for motors where the startup

time is longer than the safe stall time tE. According to

IEC 60079-7, the tE time is the time needed to heat up AC windings, when carrying the starting current IA, from the

temperature reached in rated service and at maximum ambi-

ent air temperature to the limiting temperature. A separate

speed switch is used to supervise actual starting of the motor. The motor circuit-breaker is tripped if the motor does not

reach speed in the preset time. The speed switch is part of

the motor supply itself.

7XR96 1) 60/1A
3) Speed switch

I >> >

I2 > U <

50 49 48 46 27

IE >

51N 67N

Optional I < 37

Startup super- 49T visor 3) 5)
RTD´s 4) optional

87M 7UM62

4) Pt100, Ni100, Ni120

5) 49T only available with external temperature detector device

(RTD-box 7XV5662)

Fig. 2/60 Protection of large HV motors > about 1 MW

6 Cold load pickup

By means of a binary input that can be wired from a manual

close contact, it is possible to switch the overcurrent pickup settings to less sensitive settings for a programmable amount

of time. After the set time has expired, the pickup settings auto-

matically return to their original setting. This can compensate for

initial inrush when energizing a circuit without compromising

the sensitivity of the overcurrent elements during steady-state conditions.

52 Trip
52

I >> t I > t 51.1 51.2

Binary input 51.1

(1727 > c/o)

Trip

Desensitized 51.2

during inrush 7SJ61 or 7SJ80

Busbar

52 52

Trip

10 11 12 13

I >> t I > t 51.1 51.2
Binary input 51.1 (1727 > C/O)
51.2 7SJ61 or 7SK80
Fig. 2/61 Cold load pickup

M
Typical feeder (1727 > C/O = cold load pickup of overcurrent pickup)

15
2/30 Siemens SIP · Edition No. 8

Overview
Typical protection schemes

4. Generators Generators < 500 kW (Fig. 2/62 and Fig. 2/63) Note:

If a core-balance CT is provided for sensitive ground-fault protection relay 7SJ80 with separate ground-current input can be used.

I >, IE >, t I2 >

51/51N 46

Generators, typically 1 3 MW

7SJ80

(Fig. 2/64) Note:

3
Fig. 2/62 Generator with solidly grounded neutral

Two VTs in V connection are also sufficient.

Generators > 1 3 MW (Fig. 2/65)

4
MV

Notes:
1) Functions 81 and 59 are required only where prime mover can assume excess speed and the voltage regulator may permit rise of output voltage above upper limit.
2) Differential relaying options: Low-impedance differential protection 87. Restricted ground-fault protection with low-resistance grounded neutral (Fig. 2/64).

Generator 2

I >, IE >, t I2 >

51/51N 46

0.5 to 1 rated

7SJ80
6

Fig. 2/63 Generator with resistance-grounded neutral

52 1)

Field f
81

I >, t

I2 >

IE >, t 51N

P >

U >

7UM61

I >/U < 50/27
1) 1) RG Field < 64R

59 U <
87 81 f

I2 > >

I >, t U < L. O. F. P >

46 49 51V

40 32

IG >, t 51N

2) 87N
7UM62

9 10 11 12 13

Fig. 2/64 Protection for generators 1 3 MW

Fig. 2/65 Protection for generators >1 3 MW

15
Siemens SIP · Edition No. 8 2/31

Overview
Typical protection schemes

Generators > 5 10 MW feeding into a system

For the most sensitive setting of 2 mA, we therefore need 20 mA

with isolated neutral (Fig. 2/66)

secondary ground current, corresponding to (60 / 1) × 20 mA = 1.2 A primary.

General notes:

If sufficient capacitive ground current is not available, an grounding transformer with resistive zero-sequence load can

·The setting range of the directional ground-fault protection (67N) in the 7UM6 relay is 2 1,000 mA. Depending on the

be installed as ground-current source at the station busbar. The smallest standard grounding transformer TGAG 3541 has a 20 s

current transformer accuracy, a certain minimum setting is

short-time rating of input connected to: SG = 27 kVA

required to avoid false operation on load or transient currents.

In a 5 kV system, it would deliver:

·In practice, efforts are generally made to protect about 90 % of the machine winding, measured from the machine terminals. The full ground current for a terminal fault must then be ten times the setting value, which corresponds to the fault current

3 · SG= UN

3 · 27,000 VA =
5,000 V

9.4

of a fault at 10 % distance from the machine neutral.

corresponding to a relay input current of 9.4 A × 1 / 60 A =

156 mA. This would provide a 90 % protection range with a setting of about 15 mA, allowing the use of 4 parallel connected

Relay ground-current input connected to:

Minimum relay setting:

Comments:

core-balance CTs. The resistance at the 500 V open-delta winding of the grounding transformer would then have to be

Core-balance CT 60 / 1 A: 1 single CT

2 parallel CTs

2 mA 5 mA

designed for RB = U2SEC / SG = 500 U2 / 27,000 VA = 9.26 (27 kW, 20 s)

3 parallel CTs

8 mA

4 parallel CTs

12 mA

For a 5 MVA machine and 600 / 5 A CTs with special calibration

for minimum residual false current, we would get a secondary

Three-phase CTs in residual (Holmgreen) connection

1 A CT: 50 mA 5 A CT: 200 mA

In general not suitable for sensi-

current of IG SEC = 9.4 A / (600 / 5) = 78 mA.

tive ground-fault

With a relay setting of 12 mA, the protection range would in

Three-phase CTs in residual (Holmgreen)

2 3 of secondary rated

protection
1 A CTs are not recommended in

this

case

100

12 78

connection with special

CT current In SEC this case

factory calibration

10 15 mA with 5 A CTs

to minimum residual false

currents ( 2 mA)

1)
10

11 12

Redundant protection
46 I2 >

IG 67N 27 U < 59 U > 81 f ><

13 14

51V

P L. O. F. I > t, U <

7UM61 or 7UM62

Fig. 2/66 Protection for generators > 5 10 MW

2/32 Siemens SIP · Edition No. 8

Earthing transformer UN

59N

I>/U<

50/27

67N

27 U < 64R 59 U >
81 f

59N 4) UO >

I > t, U < L. O. F. P >

I2 >

51V

87 6 I 7UM62

Overview
Typical protection schemes

Notes (Fig. 2/66):
1) The standard core-balance CT 7XR96 has a transformation ratio of 60 / 1 A.
2) Instead of an open-delta winding at the terminal VT, a 1-phase VT at the machine neutral could be used as zerosequence polarizing voltage.
3) The grounding transformer is designed for a short-time rating of 20 s. To prevent overloading, the load resistor is automatically switched off by a time-delayed zero-sequence voltage relay (59N + 62) and a contactor (52).
4) During the startup time of the generator with the open circuit-breaker, the grounding source is not available. To ensure ground-fault protection during this time interval, an auxiliary contact of the circuit-breaker can be used to change over the directional ground-fault relay function (67N) to a zero-sequence voltage detection function via binary input.

Unit trans.
87T

52
Transf. fault press 63 3)
71 Oil low

87T Unit diff.

51N Transf. neut. OC
Oil low Transf. fault press 3) 71
63

Unit aux. backup
51

2) 64R
Field grd.

64R
Field grd.

Overvolt. 59

78
Loss of sync.

Stator O.L.

Loss of field

Overfreq.
24 Volt/Hz
A

49S

Reverse 87G power

Gen. diff.

Unit aux.
51N Trans. neut. OC
87T
Trans. diff.

46
Neg. seq.

21
Sys. backup

Generators > 50 100 MW in generator transformer unit connection
(Fig. 2/67)
Notes:
1) 100 % stator ground-fault protection based on 20 Hz voltage injection
2) Sensitive rotor ground-fault protection based on 1 3 Hz voltage injection
3) Non-electrical signals can be incoupled in the protection via binary inputs (BI)
4) Only used functions shown; further integrated functions available in each relay type; for more information, please refer to part 1 of this catalog.

59/GN

1) 51/GN

Gen. neut. OV

Fig. 2/67 Protections for generators > 50 MW

Relay type

Functions4)

Number of relays required

7UM62 21 24 32 40 46 49

51GN 59GN 59 64R 64R 78

81 87G via BI: 71 63

7UM61 or 7UM62

51N optionally 21 59 81 via BI: 71 63 1

7UT612 87T 51N

optionally

1 2

7UT613 87T

Fig. 2/68 Assignment for functions to relay type

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 2/33

Overview
Typical protection schemes

Synchronization of a generator

Fig. 2/69 shows a typical connection for synchronizing a generator. Paralleling device 7VE6 acquires the line and generator

voltage, and calculates the differential voltage, frequency and

Bus 52

phase angle. If these values are within a permitted range, a

CLOSE command is issued after a specified circuit-breaker make time. If these variables are out of range, the paralleling device

automatically sends a command to the voltage and speed

controller. For example, if the frequency is outside the range, an

actuation command is sent to the speed controller. If the voltage

is outside the range, the voltage controller is activated.

U1 25 U

7VE6 f

5 5. Busbars

Busbar protection by overcurrent relays with reverse

interlocking

General note:

·Applicable to distribution busbars without substantial

(< 0.25 × IN) backfeed from the outgoing feeders.

Fig. 2/69 Synchronization of a generator

Infeed Reverse interlocking

I >, t0

I >, t

50/50N

51/51N 7SJ80

t0 = 50 ms

I > I >, t 50/50N 51/51N
7SJ80

10 11 12 13 14 15

Fig. 2/70 Busbar protection by O / C relays with reverse interlocking

Distributed busbar protection 7SS52
General notes: ·Suitable for all types of busbar schemes. ·Preferably used for multiple busbar schemes where a discon-
nector (isolator) replica is necessary. ·The numerical busbar protection 7SS52 provides additional
breaker failure protection. ·Different CT transformation ratios can be adapted numerically. ·The protection system and the disconnector (isolator) replica
are continuously self-monitored by the 7SS52. ·Feeder protection can be connected to the same CT core.

52 50BF
50
51 Bay units 50N
51N

52 50BF 50 51 50N 51N

7SS523 FO

87BB 50BF

Central unit

7SS522

Fig. 2/71 Distributed busbar protection 7SS52

2/34 Siemens SIP · Edition No. 8

Overview
Typical protection schemes

6. Power systems
Load shedding
In unstable power systems (e.g., isolated systems, emergency power supply in hospitals), it may be necessary to isolate selected loads from the power system to prevent overload of the overall system. The overcurrent-time protection functions are effective only in the case of a short-circuit.
Overloading of the generator can be measured as a frequency or voltage drop.
(Protection functions 27 and 81 available in 7RW80, 7SJ6 and 7SJ8.)

Weiteres Netz

Übererregungsschutz U >, t; U >>, t U/f >, t; U/f >>, t; U/f=f(t)

7RW80

Motorschutz ohne Wiedereinschaltverriegelung
f >,t; f <, t U <, t U >, t; U >>, t

27 59

7RW80

f >,t; f <, t; U <, t U >, t; U >>, t f >,t; f <, t; U <, t U >, t; U >>, t

81 27 59

7RW80, 7SJ62 oder 7SJ80

7RW80 oder 7SJ62

Entkopplung

Lastabwurf

Fig. 2/72 Load shedding

Load shedding with rate-of-frequency-change protection
The rate-of-frequency-change protection calculates, from the measured frequency, the gradient or frequency change df / dt. It is thus possible to detect and record any major active power loss in the power system, to disconnect certain consumers accordingly and to restore the system to stability. Unlike frequency protection, rate-of-frequency-change protection reacts before the frequency threshold is undershot. To ensure effective protection settings, it is recommended to consider requirements throughout the power system as a whole. The rate-of-frequencychange protection function can also be used for the purposes of system decoupling.
Rate-of-frequency-change protection can also be enabled by an underfrequency state.

50
Hz f

fm t 49 fa
fb

Fig. 2/73 Load shedding with rate-of-frequency-change protection

Trip circuit supervision (ANSI 74TC)
One or two binary inputs can be used for the trip circuit supervision.

VCV L+

7SJx, 7SAx, 7SDx

or any other

protective

TCo

relay

7SJx, 7SAx, 7SDx or any other BI 1 protective relay

Trip circuit faulty

TRIP

R TCo Trip contact of the relay

BI Binary input of the relay

AUX 1

AUX 1 TC Trip coil

52a

52b

Aux Circuit-breaker auxiliary

contact

R Equivalent resistor instead

of BI 2

Ucv Control voltage

CB Circuit-breaker

Fig. 2/74 Trip circuit supervision (ANSI 74TC)

1 2 3 4 5 6 7 8 9 10 11 12 13 14

15
Siemens SIP · Edition No. 8 2/35

Overview
Typical protection schemes

Disconnecting facility with flexible protection function

General note:

The SIPROTEC protection relay 7SJ64 disconnects the

switchgear from the utility power system if the generator

feeds energy back into the power system (protection function

Preverse>). This functionality is achieved by using flexible protec-

tion. Disconnection also takes place in the event of frequency

or voltage fluctuations in the utility power system (protection

functions f<, f>, U<, U>, Idir>, IEdir> / 81, 27, 59, 67, 67N).
3 Notes:

1) The transformer is protected by differential protection and

inverse or definite-time overcurrent protection functions

for the phase currents. In the event of a fault, the circuitbreaker CB1 on the utility side is tripped by a remote link.

Circuit-breaker CB2 is also tripped.

2) Overcurrent-time protection functions protect feeders 1 and

2 against short-circuits and overload caused by the connected loads. Both the phase currents and the zero currents

of the feeders can be protected by inverse and definite-time

overcurrent stages. The circuit-breakers CB4 and CB5 are

tripped in the event of a fault.

CB 1

52
Connection to power utility Switch- Customer switchgear with autonomous supply disconnector
1) 7UT612

52 CB 2

52 CB 3

7SJ64 f < f> U Sync. I >dir I E>dir Preserve >
32 81 81 27 59 25 67 67N

Busbar

7SJ61/ 2) 7SJ80 52
CB 4

7SJ61/ 2) 7SJ80 52
CB 5

Feeder 1

Feeder 2

Fig. 2/75 Example of a switchgear with autonomous generator supply

15
2/36 Siemens SIP · Edition No. 8

Overview
Protection coordination

Protection coordination
Typical applications and functions
Relay operating characteristics and their settings must be carefully coordinated in order to achieve selectivity. The aim is basically to switch off only the faulty component and to leave the rest of the power system in service in order to minimize supply interruptions and to ensure stability.
Sensitivity
Protection should be as sensitive as possible in order to detect faults at the lowest possible current level. At the same time, however, it should remain stable under all permissible load, overload and through-fault conditions. For more information: http: / / www.siemens.com / systemplanning. The Siemens engineering programs SINCAL and SIGRADE are especially designed for selective protection grading of protection relay systems. They provide short-circuit calculations, international standard characteristics of relays, fuses and circuit-breakers for easy protection grading with respect to motor starting, inrush phenomena, and equipment damage curves.

12.0 11.0 Rush 10.0 N 9.0 8.0 7.0 6.0 5.0 4.0 3.0 2.0 1.0
2

100

400

Rated transformer power (MVA)

Time constant of inrush current

Nominal power (MVA) 0.5 ... 1.0

Time constant (s)

0.16 ... 0.2

1.0 ... 10 0.2 ... 1.2

> 10 1.2 ... 720

Phase-fault overcurrent relays
The pickup values of phase overcurrent relays are normally set 30 % above the maximum load current, provided that sufficient short-circuit current is available. This practice is recommended particularly for mechanical relays with reset ratios of 0.8 to 0.85. Numerical relays have high reset ratios near 0.95 and allow, therefore, about a 10 % lower setting. Feeders with high transformer and / or motor load require special consideration.
Transformer feeders
The energizing of transformers causes inrush currents that may last for seconds, depending on their size (Fig. 2/75). Selection of the pickup current and assigned time delay have to be coordinated so that the inrush current decreases below the relay overcurrent reset value before the set operating time has elapsed. The inrush current typically contains only about a 50 % fundamental frequency component. Numerical relays that filter out harmonics and the DC component of the inrush current can therefore be set to be more sensitive. The inrush current peak values of Fig. 2/76 will be reduced to more than one half in this case. Some digital relay types have an inrush detection function that may block the trip of the overcurrent protection resulting from inrush currents.

Fig. 2/76 Peak value of inrush current
Ground-fault protection relays
Ground-current relays enable a much more sensitive setting, because load currents do not have to be considered (except 4-wire circuits with 1-phase load). In solidly and low-resistance grounded systems, a setting of 10 to 20 % rated load current can generally be applied. High-resistance grounding requires a much more sensitive setting, on the order of some amperes primary. The ground-fault current of motors and generators, for example, should be limited to values below 10 A in order to avoid iron burning. In this case, residual-current relays in the start point connection of CTs cannot be used; in particular, with rated CT primary currents higher than 200 A. The pickup value of the zero-sequence relay would be on the order of the error currents of the CTs. A special core-balance CT is therefore used as the ground-current sensor. The core-balance CT 7XR96 is designed for a ratio of 60 /1 A. The detection of 6 A primary would then require a relay pickup setting of 0.1 A secondary. An even more sensitive setting is applied in isolated or Petersen coil grounded systems where very low ground currents occur with 1-phase-to-ground faults. Settings of 20 mA and lower may then be required depending on the minimum ground-fault current. Sensitive directional ground-fault relays (integrated into the relays 7SJ62, 63, 64, 7SJ80, 7SK80, 7SA6) allow settings as low as 5 mA.

1 2 3 4 5 6 7 8 9 10 11 12

15
Siemens SIP · Edition No. 8 2/37

Overview
Protection coordination

1 2 3 4 5 6 7 8 9 10 11 12 13

Motor feeders
The energization of motors causes a starting current of initially 5 to 6 times the rated current (locked rotor current).
A typical time-current curve for an induction motor is shown in Fig. 2/77.
In the first 100 ms, a fast-decaying asymmetrical inrush current also appears. With conventional relays, it was common practice to set the instantaneous overcurrent stage of the short-circuit protection 20 to 30 % above the locked rotor current with a short-time delay of 50 to 100 ms to override the asymmetrical inrush period.
Numerical relays are able to filter out the asymmetrical current component very rapidly so that the setting of an additional time delay is no longer applicable.
The overload protection characteristic should follow the thermal motor characteristic as closely as possible. The adaptation is made by setting the pickup value and the thermal time constant, using the data supplied by the motor manufacturer. Furthermore, the locked-rotor protection timer has to be set according to the characteristic motor value.

10,000
1,000 Time in seconds 100
10
1
0.1
0.01
0.001 0 1 2 3 4 5 6 7 8 9 10 Current in multiplies of full-load amps

Motor starting current Locked-rotor current Overload protection characteristic

High set instantaneous O/C stage Motor thermal limit curve Permissible locked-rotor time

Fig. 2/77 Typical motor current-time characteristics

Time grading of overcurrent relays (51)
The selectivity of overcurrent protection is based on time grading of the relay operating characteristics. The relay closer to the infeed (upstream relay) is time-delayed against the relay further away from the infeed (downstream relay). The calculation of necessary grading times is shown in Fig. 2/79 by an example for definite-time overcurrent relays.
The overshoot times take into account the fact that the measuring relay continues to operate due to its inertia, even if when the fault current is interrupted. This may be high for mechanical relays (about 0.1 s) and negligible for numerical relays (20 ms).

Time

Main Feeder

Maximum feeder fault level

0.2-0.4 seconds Current

Fig. 2/78 Coordination of inverse-time relays

Inverse-time relays (51)
For the time grading of inverse-time relays, in principle the same rules apply as for the definite-time relays. The time grading is first calculated for the maximum fault level and then checked for lower current levels (Fig. 2/78).
If the same characteristic is used for all relays, or if when the upstream relay has a steeper characteristic (e.g., very much over normal inverse), then selectivity is automatically fulfilled at lower currents.

lnstantaneous overcurrent protection (50)
This is typically applied on the final supply load or on any protection relay with sufficient circuit impedance between itself and the next downstream protection relay. The setting at transformers, for example, must be chosen about 20 to 30 % higher than the maximum through-fault current. The relay must remain stable during energization of the transformer.

Differential relay (87)
Transformer differential relays are normally set to pickup values between 20 and 30 % of the rated current. The higher value has to be chosen when the transformer is fitted with a tap changer.
Restricted ground-fault relays and high-resistance motor / generator differential relays are, as a rule, set to about 10 % of the rated current.

15
2/38 Siemens SIP · Edition No. 8

Overview
Protection coordination

Calculation example
The feeder configuration of Fig. 2/80 and the associated load and short-circuit currents are given. Numerical overcurrent relays 7SJ80 with normal inverse-time characteristics are applied.
The relay operating times, depending on the current, can be derived from the diagram or calculated with the formula given in Fig. 2/81.
The Ip / IN settings shown in Fig. 2/80 have been chosen to get pickup values safely above maximum load current.
This current setting should be lowest for the relay farthest downstream. The relays further upstream should each have equal or higher current settings.
The time multiplier settings can now be calculated as follows:

Station C:
·For coordination with the fuses, we consider the fault in location F1. The short-circuit current Iscc. max. related to 13.8 kV is 523 A. This results in 7.47 for I / Ip at the overcurrent relay in location C.
·With this value and Tp = 0.05, an operating time of tA = 0.17 s can be derived from Fig. 2/81.
·This setting was selected for the overcurrent relay to get a safe grading time over the fuse on the transformer low-voltage side. Safety margin for the setting values for the relay at station C are therefore:
·Pickup current: Ip / IN = 0.7 ·Time multiplier: Tp = 0.05.
Station B:
The relay in B has a primary protection function for line B-C and a backup function for the relay in C. The maximum through-fault current of 1.395 A becomes effective for a fault in location F2. For the relay in C, an operating time time of 0.11 s (I / Ip = 19.93) is obtained.
It is assumed that no special requirements for short operating times exist and therefore an average time grading interval of 0.3 s can be chosen. The operating time of the relay in B can then be calculated.

· tB = 0.11 + 0.3 = 0.41 s

· 1,395 A

Value

220 A

6.34

(Fig.

2/80)

· With the operating time 0.41 s and Ip / IN = 6.34, Tp = 0.11 can be derived from Fig. 2/81.

52M

Operating time

51M

52F

51F

Fault

inception detection

t 51F

Set time delay

0.2-0.4 Time grading

t 52F Circuit-breaker
interruption time

Interruption of fault current

Overshoot*
tOS Margin tM

t 51M
*also called overtravel or coasting time

Time grading

trs = t51M t51F = t52F + tOS + tM

Example 1

tTG =0.10 s + 0.15 s + 0.15 s = 0.40 s

Oil circuit-breaker

t52F = 0.10 s

Mechanical relays

tOS = 0.15 s

Safety margin for measuring errors, etc.

tM = 0.15 s

Example 2

tTG = 0.08 + 0.02 + 0.10 = 0.20 s

Vacuum circuit-breaker

t52F = 0.08 s

Numerical relays

tOS = 0.02 s

Safety margin

tM = 0.10 s

Fig. 2/79 Time grading of overcurrent-time relays

F4 B

F3 C

13.8 kV/ 0.4 kV

Fuse: D 160 A

13.8 kV 51
7SJ80

51 7SJ80

625 kVA L.V. 75 5.0 %

Load F1 Load
Load

Station Max. load A

ISCC. max*
A

CT ratio

Ip / IN**

Iprim*** A

Iscc.max Iprim

300 4,500 400 / 5 1.0

400

11.25

170 2,690 200 / 5 1.1

220

12.23

1,395 100 / 5 0.7

19.93

523

*) **) ***)

ISCC. max = Maximum short-circuit current

Ip / IN

= Relay current multiplier setting

Iprim

= Primary setting current corresponding to Ip / IN

Fig. 2/80 Time grading of inverse-time relays for a radial feeder

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 2/39

Overview
Protection coordination

1 2 3 4 5 6 7 8 9 10 11 12 13 14

The setting values for the relay at station B are: ·Pickup current: Ip / IN = 1.1 ·Time multiplier Tp = 0.11
Given these settings, the operating time of the relay in B for a close fault in F3 can also be checked: The short-circuit current increases to 2,690 A in this case (Fig. 2/80). The corresponding I / Ip value is 12.23. ·With this value and the set value of Tp = 0.11, an operating
time of 0.3 s is obtained again (Fig. 2/81).
Station A: ·Adding the time grading interval of 0.3 s, the desired operat-
ing itme is tA = 0.3 + 0.3 = 0.6 s.
Following the same procedure as for the relay in station B, the following values are obtained for the relay in station A:
·Pickup current: Ip / IN = 1.0 ·Time multiplier Tp = 0.17 ·For the close-in fault at location F4, an operating time of
0.48 s is obtained.
The normal way
To prove the selectivity over the whole range of possible shortcircuit currents, it is normal practice to draw the set of operating curves in a common diagram with double log scales. These diagrams can be calculated manually and drawn point-by-point or constructed by using templates.
Today, computer programs are also available for this purpose. Fig. 2/82 shows the relay coordination diagram for the selected example, as calculated by the Siemens program SIGRADE (Siemens Grading Program).
Note:
To simplify calculations, only inverse-time characteristics have been used for this example. About 0.1 s shorter operating times could have been reached for high-current faults by additionally applying the instantaneous zones I>> of the 7SJ80 relays.

100

10
5 4 3 2

0.50 0.4 0.3
0.2

0.1

Tp [s] 3.2 1.6 0.8 0.4 0.2 0.1 0.05

0.05

2 4 6 8 10 20 p [A]

Fig. 2/81 Normal inverse-time characteristic of the 7SJ80 relay

Coordination of overcurrent relays with fuses and low-voltage trip devices
The procedure is similar to the above-described grading of overcurrent relays. A time interval of between 0.1 and 0.2 s is usually sufficient for a safe time coordination.
Strong and extremely inverse characteristics are often more suitable than normal inverse characteristics in this case. Fig. 2/83 shows typical examples.
Simple distribution substations use a power fuse on the secondary side of the supply transformers (Fig. 2/83a).
In this case, the operating characteristic of the overcurrent relay at the infeed has to be coordinated with the fuse curve.

Normal inverse t = (I/ Ip0).01.0421 · Tp(s)
Strong inverse characteristics may be used with expulsion-type fuses (fuse cutouts), while extremely inverse versions adapt better to current limiting fuses.
In any case, the final decision should be made by plotting the curves in the log-log coordination diagram.
Electronic trip devices of LV breakers have long-delay, shortdelay and instantaneous zones. Numerical overcurrent relays with one inverse-time and two definite-time zones can closely be adapted to this (Fig. 2/83b).

15
2/40 Siemens SIP · Edition No. 8

Overview
Protection coordination

Fig. 2/82 Overcurrent-time grading diagram

IN Bus-A
/5 A 52 7SJ80 Bus-B
/5 A 52 7SJ80 Bus-C
/5 A 52 7SJ80

TR fuse

13.8/0.4 kV 625 kVA 5.0%
VDE 160

Setting range Ip = 0.10 4.00 IN Tp = 0.05 3.2 s I>> = 0.1 25 IN
Ip = 0.10 4.00 IN Tp = 0.05 3.2 s I>> = 0.1 25 IN
Ip = 0.10 4.00 IN Tp = 0.05 3.2 s I>> = 0.1 25 IN
HRC fuse 160 A

Time

Inverse-time relay

Other consumers

MV bus 51
Fuse

Fuse

0.2 s

n a LV bus

Current

Maximum fault available at HV bus

Fig. 2/83 Coordination of an overcurrent relay with an MV fuse and low-voltage breaker trip device

Ip = 1.0 IN Tp = 0.17 s I>> = Ip = 1.0 IN Tp = 0.11 s I>> =
Ip = 0.7 IN Tp = 0.05 s I>> =

1 2 3 4 5 6 7 8 9 10 11

Coordination of distance relays
The distance relay setting must take into account the limited relay accuracy, including transient overreach (5 %, according to IEC 60255-6), the CT error (1 % for class 5P and 3 % for class 10P) and a security margin of about 5 %. Furthermore, the line parameters are often only calculated, not measured. This is a further source of errors. A setting of 80 to 85 % is therefore common practice; 80 % is used for mechanical relays, while 85 % can be used for the more accurate numerical relays.

Where measured line or cable impedances are available, the protected zone setting may be extended to 90 %. The second and third zones have to keep a safety margin of about 15 to 20 % to the corresponding zones of the following lines. The shortest following line always has to be considered (Fig. 2/84).
As a general rule, the second zone should at least reach 20 % over the next station to ensure backup for busbar faults, and the third zone should cover the longest following line as backup for the line protection.

12 13 14

15
Siemens SIP · Edition No. 8 2/41

Overview
Protection coordination

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Grading of zone times
The first zone normally operates undelayed. For the grading of the time delays of the second and third zones, the same rules as for overcurrent relays apply (Fig. 2/79, page 2/41). For the quadrilateral characteristics (relays 7SA6 and 7SA5), only the reactance values (X values) have to be considered for the protected zone setting. The setting of the R values should cover the line resistance and possible arc or fault resistances. The arc resistance can be roughly estimated as follows:

[ ] RARC

2.5 larc I SSC Min

larc = Arc length in mm
ISCC Min = Minimum short-circuit current in kA
·Typical settings of the ratio R / X are: Short lines and cables ( 10 km): R / X =2 to 6 Medium line lengths < 25 km: R / X =2 Longer lines 25 to 50 km: R / X =1

Shortest feeder protectable by distance relays

The shortest feeder that can be protected by underreaching distance zones without the need for signaling links depends on the shortest settable relay reactance.

XPrim Min

X Relay Min

VTratio CTratio

lmin

XPrim Min X L ine

The shortest setting of the numerical Siemens relays is 0.05 for 1 A relays, corresponding to 0.01 for 5 A relays. This allows distance protection of distribution cables down to the range of some 500 meters.

Operating

time t2

Z1A

Z2A Z1B

Z3A Z2B Z1C

ZLA-B B

ZLB-C C

Load

Z1A = 0.85 · ZLAB Z2A = 0.85 · (ZLAB + Z1B) Z2A = 0.85 · (ZLAB + Z2B)

ZLC-D D Load

Fig. 2/84 Grading of distance zones

X X3A
X2A X1A

D C B

R1A R2A R3A

Breaker failure protection setting
Most numerical relays in this guide provide breaker failure (BF) protection as an integral function. The initiation of the BF protection by the internal protection functions then takes place via software logic. However, the BF protection function may also be initiated externally via binary inputs by an alternate protection. In this case, the operating time of intermediate relays (BFI time) may have to be considered. Finally, the tripping of the infeeding breakers requires auxiliary relays, which add a small time delay (BFI) to the overall fault clearing time. This is particularly the case with one-breaker-and-a-half or ring bus arrangements where a separate breaker failure relay (7VK61) is used per breaker (Fig. 2/79, Fig. 2/80).
The decisive criterion of BF protection time coordination is the reset time of the current detector (50BF), which must not be exceeded under any condition during normal current interruption. The reset times specified in the Siemens numerical relay manuals are valid for the worst-case condition: interruption of a fully offset short-circuit current and low current pickup setting (0.1 to 0.2 times rated CT current).

Fig. 2/85 Operating characteristics of Siemens distance relays
The reset time is 1 cycle for EHV relays (7SA6 / 52, 7VK61) and 1.5 to 2 cycles for distribution type relays (7SJ**). Fig. 2/87 (next page) shows the time chart for a typical breaker failure protection scheme. The stated times in parentheses apply for transmission system protection and the times in square brackets for distribution system protection.

15
2/42 Siemens SIP · Edition No. 8

Overview
Protection coordination

High-impedance differential protection; verification of design
The following design data must be established: CT data

50BF

The prerequisite for high-impedance scheme is that all CTs used for that scheme must have the same ratio. They should also be of low leakage flux design according to Class PX of IEC 60044-1 (former Class X of BS 3938) or TPS of IEC 60044-6, when used for high-impedance busbar protection scheme. When used for restricted ground-fault differential protection of e.g. a transformer winding especially in solidly grounded networks,

P1: primary protection

P2: alternate protection

50BF

A N

CTs of Class 5P according to IEC 60044-1 can be used as well. In each case the excitation characteristic and the secondary

Fig. 2/86 Breaker failure protection, logic circuit

winding resistance are to be provided by the manufacturer. The knee-point voltage of the CT must be at least twice the relay

pickup voltage to ensure operation on internal faults.

Fault incidence

BFI =

breaker failure

Normal interrupting time

initiation time

The relay

Current

(intermediate

The relay can be either:

detector (50 BF)

relays, if any)

Protect. Breaker inter. reset time

Margin

BFT =

a) dedicated design high-impedance relay, e.g., designed as

breaker failure

a sensitive current relay Reyrolle 7SR23 with external series

time (1~)

time (2~)

tripping time

(1~)

(2,5~)

(auxilary relays,

resistor Rstab. If the series resistor is integrated into the relay, the setting values may be directly applied in volts; or
b) digital overcurrent protection relay with sensitive current

[2~]

[4~]

0,5~

[2~]
(5~) [8~]

[2,5~]

if any)

0,5~

(2~) [4~]

input, like 7SJ6 or 7SR1 (Argus-C). To the input of the relay
a series stabilizing resistor Rstab will be then connected as a rule in order to obtain enough stabilization for the high-impedance
scheme. Typically, a non-linear resistor V (varistor) will be also

BFI

BF timer (F) (62BF)

BFT Adjacent

Total breaker failure interrupting time

breaker

int. time

(9~) [15~]

connected to protect the relay and wiring against overvoltages.

Sensitivity of the scheme

Fig. 2/87 Time coordination of BF time setting
8

For the relay to operate in the event of an internal fault, the

primary current must reach a minimum value to supply the relay

pickup current (Iset), the varistor leakage current (Ivar) and the

magnetizing currents of all parallel-connected CTs at the set pickup voltage. A low relay voltage setting and CTs with low

magnetizing current therefore increase the protection sensitivity

Stability during external faults
This check is made by assuming an external fault with maximum through-fault current and full saturation of the CT in the faulty feeder. The saturated CT is then substituted with its secondary winding resistance RCT, and the appearing relay voltage VR corresponds to the voltage drop of the in-feeding currents (through-fault current) across RCT and Rlead. The current (voltage) at the relay must, under this condition, stay reliably below the relay pickup value.
In practice, the wiring resistances Rlead may not be equal. In this case, the worst condition with the highest relay voltage (corresponding to the highest through-fault current) must be sought by considering all possible external feeder faults.
Setting
The setting is always a trade-off between sensitivity and stability. A higher voltage setting leads not only to enhanced through-fault stability but also to higher CT magnetizing and varistor leakage currents, resulting consequently in a higher primary pickup current.

UK = CT knee-point voltage UR = RR · IR UK = 2 · UR
Fig. 2/88 Principle connection diagram for high-impedance restricted ground-fault protection of a winding of the transformer using SIPROTEC digital overcurrent relay (e.g. 7SJ61)

Relay setting Urms C

125

450

125 240

900

0.25 0.25

Varistor type 600 A / S1 / S256 600 A / S1 / S1088

10 11 12 13 14

Siemens SIP · Edition No. 8 2/43

Overview
Protection coordination

Calculation example:

Moreover, Rstab must have a short time rating large enough to withstand

Restricted ground fault protection for the 400 kV winding of 400 MVA power transformer with Ir, 400 kV = 577 A installed in a switchgear with

the fault current levels before the fault is cleared. The time duration of
0.5 seconds can be typically considered (Pstab, 0.5s) to take into account longer fault clearance times of back-up protection.

rated withstand short-circuit current of 40 kA. Given:

The rms voltage developed across the stabilizing resistor is decisive for the thermal stress of the stabilizing resistor. It is calculated according to

N = 4 CTs connected in parallel; Ipn / Isn = 800 A / 1 A CT ratio; Uk = 400 V CT Knee-point voltage; Im = 20 mA CT magnetizing current at Uk;

RCT = 3 CT internal resistance;

Rlead = 2 secondary wiring (lead) resistance

formula:

Urms,relay

= 1.3 4 Uk3 Rstab Ik,max,int

I sn Ipn

= 1.3 4

4003 1000 50

= 1738.7 V

Relay: 7SJ612; Time overcurrent 1Phase input used with setting range Iset = 0.003 A to 1.5 A in steps of 0.001 A; relay internal burden Rrelay = 50 m
Stability calculation

The resulting short-time rating Pstab, 0.5 s equals to:

Pstab,0.5s

2
= Urms,relay Rstab

= 17392 1000

= 3023 W

Us ,min

Ik, max, thr

--Isn Ipn

(RCT

Rlead)

10,000

1 800

(3+2)

62.6

Check whether the voltage limitation by a varistor is required
The relay should normally be applied with an external varistor which should be connected across the relay and stabilizing resistor input terminals. The

with Ik,max,thr taken as 16 . Ir,400kV = 16 . 577 A = 9,232 A, rounded up to 10 kA. varistor limits the voltage across the terminals under maximum internal

The actual stability voltage for the scheme Us can be taken with enough safety margin as Us = 130 V (remembering that 2Us < Uk). Fault setting calculation
For the desired primary fault sensitivity of 125 A, which is approx. 22 %

fault conditions. The theoretical voltage which may occur at the terminals

can be determined according to following equation:

Uk, max, int

Ik, max, int

--Isn Ipn

(Rrelay

Rstab)

40,000

1 ---- 800

(0.05+1000)

50003

of the rated current of the protected winding Ir, 400 kV (i.e. Ip, des = 125 A) with Ik,max,int taken as the rated short-circuit current of the switchgear = 40 kA. the following current setting can be calculated:

Iset

Ip,des

--Isn Ipn

--U--s Uk

125

1 ---- 800

0.02

130 ---- 400

0.13

Stabilizing resistor calculation

The resulting maximum peak voltage across the panel terminals (i.e. tie with relay and Rstab connected in series):
( ) Û max,relay = 2 2Uk Uk,max,int = 2 2 400(50003 - 400) = 12600 V

From the Us and Iset values calculated above the value of the stabilizing resistor Rstab can be calculated:

Since Umax, relay > 1.5 kV the varistor is necessary.

Rstab

--Us Iset

Rrelay

130 ---- 0.13

0.05

1,000

Exemplarily, a METROSIL of type 600A / S1 / Spec.1088 can be used ( = 0.25, C = 900). This Metrosil leakage current at voltage setting Us =130 V equals to

where the relay resistance can be neglected. The stabilizing resistor Rstab can be chosen with a necessary minimum

( ) Irms = 0.52

U--se--t, rm--s .--2

1/
= 0.91 mA

continuous power rating Pstab,cont of:

Pstab,cont

--Us--2 Rstab

1302 = = 16.9 W
1000

and can be neglected by the calculations, since its influence on the proposed fault-setting is negligible.

10 11 12 13 14 15

A higher voltage setting also requires a higher knee-point voltage of the CTs and therefore greater size of the CTs. A sensitivity of 10 to 20 % of Ir (rated current) is typical for restricted ground-fault protection. With busbar protection, a pickup value Ir is normally applied. In networks with neutral grounding via impedance the fault setting shall be revised against the minimum ground fault conditions.
Non-linear resistor (varistor)
Voltage limitation by a varistor is needed if peak voltages near or above the insulation voltage (2 kV ... 3 kV) are expected. A limitation to Urms = 1,500 V is then recommended. This can be checked for the maximum internal fault current by applying the formula shown for Umax relav. A restricted ground-fault protection may sometimes not require a varistor, but a busbar protection in general does. However, it is considered a good practice to equip with a varistor all high impedance protection installations. The electrical varistor characteristic of a varistor can be expressed as U = C I where C and are the varistor constants.

CT requirements for protection relays
Instrument transformers
Instrument transformers must comply with the applicable IEC recommendations IEC 60044 and 60186 (PT), ANSI / IEEE C57.13 or other comparable standards.
Voltage transformers (VT)
Voltage transformers (VT) in single-pole design for all primary voltages have typical single or dual secondary windings of 100, 110 or 115 V / 3 with output ratings between 10 and 50 VA suitable from most application with digital metering and protection equipment, and accuracies of 0.1 % to 6 % to suit the particular application. Primary BIL values are selected to match those of the associated switchgear.
Current transformers
Current transformers (CT) are usually of the single-ratio type with wound or bar-type primaries of adequate thermal rating. Single, double or triple secondary windings of 1 or 5 A are standard. 1 A rating should, however, be preferred, particularly in HV and EHV stations, to reduce the burden of the connected lines. Output power (rated burden in VA), accuracy and saturation characteristics (rated symmetrical short-circuit current limiting

2/44 Siemens SIP · Edition No. 8

Overview
Protection coordination

factor) of the cores and secondary windings must meet the requirements of the particular application.The CT classification code of IEC is used in the following:
·Measuring cores These are normally specified 0.2 % or 0.5 % accuracy (class 0.2 or class 0.5), and an rated symmetrical short-circuit current limiting factor FS of 5 or 10. The required output power (rated burden) should be higher than the actually connected burden. Typical values are 2.5, 5 or 10 VA. Higher values are normally not necessary when only electronic meters and recorders are connected. A typical specification could be: 0.5 FS 10, 5 VA.
·Cores for billing values metering In this case, class 0.25 FS is normally required.
·Protection cores The size of the protection core depends mainly on the maximum short-circuit current and the total burden (internal CT burden, plus burden of connected lines plus relay burden) Furthermore, a transient dimensioning factor has to be considered to cover the influence of the DC component in the short-circuit current.

Glossary of used abbreviations (according to IEC 60044-6, as defined)

Kssc
K'ssc Ktd Issc max Ipn Isn Rct

= Rated symmetrical short-circuit current factor (example: CT cl. 5P20 Kssc = 20)
= Effective symmetrical short-circuit current factor
= Transient dimensioning factor
= Maximum symmetrical short-circuit current
= CT rated primary current
= CT rated secondary current
= Secondary winding d.c. resistance at 75 °C / 167 °F (or other specified temperature)

Rb R'b TP UK Rrelay
Rlead

= Rated resistive burden = Rlead + Rrelay = connected resistive burden = Primary time constant (net time constant) = Kneepoint voltage (r.m.s.) = Relay burden
2 · · l =
A

with l
A

= Single conductor length from CT to relay in m = Specific resistance = 0.0175 mm2 / m (copper wires)
at 20 °C / 68 °F (or other specified temperature) = Conductor cross-section in mm2

In general, an accuracy of 1 % in the range of 1 to 2 times nominal current (class 5 P) is specified. The rated symmetrical short-circuit current factor KSSC should normally be selected so that at least the maximum short-circuit current can be transmitted without saturation (DC component is not considered).
This results, as a rule, in rated symmetrical short-circuit current factors of 10 or 20 depending on the rated burden of the CT in relation to the connected burden. A typical specification for protection cores for distribution feeders is 5P10, 10 VA or 5P20, 5 VA.

The requirements for protective current transformers for transient performance are specified in IEC 60044-6. In many practical cases, iron-core CTs cannot be designed to avoid saturation under all circumstances because of cost and space reasons, particularly with metal-enclosed switchgear.
The Siemens relays are therefore designed to tolerate CT saturation to a large extent. The numerical relays proposed in this guide are particularly stable in this case due to their integrated saturation detection function.

CT dimensioning formulae

K'ssc

Kssc

Rct +Rb Rct + R'b

(effective)

with

K'ssc

Ktd

Isccmax Ipn

(required)

The effective symmetrical short-circuit current factor K'SSC can be calculated as shown in the table above.

The rated transient dimensioning factor Ktd depends on the type of relay and the primary DC time constant. For relays with a
required saturation free time from 0.4 cycle, the primary (DC)
time constant TP has little influence.

CT design according to BS 3938 / IEC 60044-1 (2000)

IEC Class P can be approximately transfered into the IEC Class PX (BS Class X) standard definition by following formula:

(Rb +Rct)· In· Kssc 1.3

Example: IEC 60044: 600 / 1, 5P10, 15 VA, Rct = 4

(15 + 4) · 1 · 10

IEC PX or BS:

1.3

146

Rct = 4

For CT design according to ANSI / IEEE C 57.13 please refer to page 2/50

The CT requirements mentioned in Table 2/2 are simplified in order to allow fast CT calculations on the safe side. More accurate dimensioning can be done by more intensive calculation with Siemens's CTDIM (www.siemens.com / ctdim) program. Results of CTDIM are released by the relay manufacturer.

Adaption factor for 7UT6, 7UM62 relays (limited resolution of measurement)

Ipn INrelay Ipn · 3 · UnO INrelay

FAdap

InO

Isn

SNmax

Isn

Request: 8

7SD52, 53, 610, when transformer inside protected zone

In-p ri-C Tm ax

In-pri-CTmin Transformer Ratio*

* If transformer in protection zone, else 1

In-pri-CT-Transf-Site 2 · In-Obj-Transf-Site AND

In-pri-CT-Transf-Site In-Obj-Transf-Site with

InO UnO INrelay SNmax

= Rated current of the protected object = Rated voltage of the protected object = Rated current of the relay = Maximun load of the protected object
(for transformers: winding with max. load)

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 2/45

Overview
Protection coordination

Relay type
1

Overcurrent-time

and motor protection

7SJ61, 62, 63, 64 7SJ80, 7SK80

Transient dimensioning factor Ktd

Min. required sym. shortcircuit current factor K'ssc

K'ssc

IHigh set point Ipn

at least: 20

Min. required knee-point voltage Uk

IHigh set point 1.3 · Ipn

(Rct

R'b)

Isn

least:

1.3

(Rct

R'b)

Isn

Line differential protection

Busbar / Gen. /

K'ssc

(without distance function)

Transformer Line

7SD52x, 53x, 610 (50 / 60 Hz) 1.2

1.2

Motor 1.2

Iscc max (ext. fault) Ktd ·

Transformer / generator

Busbar / Gen. /

Ipn

differential protection

Transformer Line

Motor

and (only for 7SS):

7UT612, 7UT612 V4.0

7UT613, 633, 635, 7UT612 V4.6 3

7UM62

Iscc max(ext.fault) 100 Ipn

Busbar protection

for stabilizing factors k 0.5 (measuring range)

7SS52

0.5

Ktd

Iscc max(ext. fault) 1.3 · Ipn

(Rct

R'b)

Isn

and (only for 7SS):

Iscc max(ext.fault) 100 Ipn
(measuring range)

Distance protection 7SA522, 7SA6, 7SD5xx (with distance function)

primary DC time constant Tp [ms]

30 50 100 200

Ktd (a)

K'ssc

Ktd

(a)

Iscc max(closein fault) Ipn

Ktd

(a)·

Iscc max(closein fault) 1.3 · Ipn

(Rct

R'b)

Isn

Ktd (b)

5 and:

and:

Ktd

(b)

Iscc max(zone1 endfault) Ipn

Ktd

(b)

Iscc max(zone1 endfault) 1.3 · Ipn

(Rct

R'b)

Isn

Table 2/2 CT requirements
7

8 132 kV, 50 Hz

9 10 11 12 13

-T (G S2) 6,000/1 A 5P20 20 VA Rct = 18

-G1 120 MVA 13.8 kV, 50 Hz x"d = 0.16
G
3~

-T (T LV1)) 6,000/1 A 5P20 20 VA Rct = 18

35.8 kA

34.5 kA

I = 60 m A = 4 mm2

I = 40 m A = 4 mm2
-G2

7UM62

-T1 240/120/120 MVA 132/13.8/13.8 kV 50 Hz uk 1-2 = 14 %
2

7.5 kA

1 = HV

2 = LV1

3 = LV2

-T (T HV) 1,200/5 A 5P20 50 VA Rct = 0.96
l = 100 m A = 4 mm2

7UT633

CB arrangement inside power station is not shown x"d = Generator direct axis subtransient reactance in p.u. uk 1-2 = Transformer impedance voltage HV side LV side in % Rrelay = Assumed with 0.1 , (power consumption for above relays is below 0.1 VA)
1) Current from side 3 is due to uk 2-3 and x"d of G2 in most cases negligible

-T (L end 1) 1,000/5 A BS cl.X Uk = 200 V Rct = 0.8
l = 60 m A = 4 mm2
7SD52*)
*) without distance function

-T (L end 2) 1,500/1 A
7SD52

Fig. 2/89 Example 1 CT verification for 7UM62, 7UT6, 7SD52 (7SD53, 7SD610)

17 kA (given)

15
2/46 Siemens SIP · Edition No. 8

Overview
Protection coordination

-T (G S2), 7UM62

-T (T LV1), 7UT633

-T (T HV), 7UT633

-T (L end 1), 7SD52

Iscc

max

(ext.

fault)

= c·SNG 3 · UNG x"d

Iscc

max

(ext.

fault)

= SNT 3 · UNT uk"

Iscc

max

(ext.

fault)

SNT 3 · UNT uk"

Iscc max (ext. fault) = 17 kA (given)

1.1 · 120,000 kVA

120,000 kVA

240,000 kVA

= = 34,516 A = = 35,860 A = = 7,498 A

3 · 13.8 kV · 0.16

3 · 13.8 kV · 0.14

3 · 132 kV · 0.14

Ktd = 5 (from Table 2/2)

Ktd = 3 (from Table 2/2)

Ktd = 1.2 (from Table 2/2)

K'ssc

Ktd

Iscc max (ext.fault) Ipn

K'ssc

Ktd

Iscc max (ext.fault) Ipn

K'ssc

Ktd

Iscc max (ext.fault) Ipn

31,378 A = 5 · = 28.8

35,860 A = 3 · = 17.9

7,498 A = 3 · = 18,7

6,000 A

1,200 A

Sn I2sn

20 VA
1 A2

Sn I2sn

20 VA
1 A2

Sn I2sn

50 VA (5 A)2

R'b = Rlead + Rrelay

2 · p · l

0.1

2 · p · l

0.1

2 · p · l

0.1

2 · p · l

0.1

mm2

2 · 0.0175 · 60 m

2 · 0.0175 · 640 m

2 · 0.0175 · 100 m

2 · 0.0175 · 60 m

m =
4 mm2

+ 0.1 = 0.625

K'ssc

Kssc

Rct +Rb Rct + R'b

18 + 20 = 20 · = 40.8
18 + 0.625

K'ssc required = 28.8, Kssc effective = 40.8 28.8 < 40.8
CT dimensioning is ok

FAdap

Ipn· 3· UnO SNmax

INrelay Isn

+ 0.1 = 0.450

K'ssc

Kssc

Rct +Rb Rct + R'b

18 + 20 = 20 · = 41.2
18 + 0.450

K'ssc required = 17.9, Kssc effective = 41.2 17.9 < 41.2
CT dimensioning is ok

FAdap

Ipn· 3· UnO SNmax

INrelay Isn

+ 0.1 = 0.975

+ 0.1 = 0.625

K'ssc

Kssc

Rct +Rb Rct + R'b

0.96 + 2 = 20 · = 30.6
0.96 + 0.975

K'ssc required = 18.7, Kssc effective = 30.6 18.7 < 30.6
CT dimensioning is ok

Ktd

·Isccmax (ext. fault) 1.3 · Ipn

(Rct

R'b)

Isn

17,000 A = 1.2 · · (0.8 + 0.625 ) ·5 A
1.3 · 1,000 A

= 111.8 V UK required = 111.8 V, UK effective = 200 V 111.8 V < 200 V
CT dimensioning is ok

FAdap

Ipn· 3· UnO SNmax

INrelay Isn

Ipnmax 8 Ipn min

6,000 A · 3 · 13.8 kV 1 A

1,200 A · 3 · 132 kV 5 A

= · = · = ·

120,000 kVA

1 A

240,000 kVA

1 A

240,000 kVA

5 A

1,500 A = 1.5 8 ok! 1,000 A

= 1.195 1.195 8 ok!

= 0.598 0.598 8 ok!

= 1.143 1.143 8 ok!

Table 2/3 Example 1 (continued) verification of the numerical differential protection

8 9 10 11 12 13

Attention (only for 7UT6 V4.0): When low-impedance REF is used, the request for the REF side (3-phase) is:
¼ FAdap 4, (for the neutral CT: FAdap 8)

Further condition for 7SD52x, 53x, 610 relays (when used as line differential protection without transformer inside protected zone): Maximum ratio between primary currents of CTs at the end of the protected line:
IIppnn mmainx 8

14 15

Siemens SIP · Edition No. 8 2/47

Overview
Protection coordination

Given case:
1

600/1 5 P 10,

15 VA,

Rct = 4

4 Fig. 2/90 Example 2

l = 50 m A = 6 mm2
7SS52
scc.max.= 30 kA

Iscc max

30,000 A

Ipn

600 A

According to Table 2/2, page 2/48 Ktd = ½

K'ssc

· 50 = 25 2

Analog static relays in general have burdens below about 1 VA.

Mechanical relays, however, have a much higher burden, up to the order of 10 VA. This has to be considered when older relays are connected to the same CT circuit.

In any case, the relevant relay manuals should always be consulted for the actual burden values.

Burden of the connection leads The resistance of the current loop from the CT to the relay has to be considered:

Rlead

2 · · l =
A

= Single conductor length from the CT to the relay in m

Specific resistance:

· mm2

= 0.0175 (copper wires) at 20 °C / 68 °F m

= Conductor cross-section in mm2

CT design according to ANSI / IEEE C 57.13

7 8 9 10 11 12 13

15 VA

= = 15 1 A2

Rrelay = 0.1

Class C of this standard defines the CT by ist secondary terminal voltage at 20 times rated current, for which the ratio error shall not exceed 10 %. Standard classes are C100, C200, C400 and C800 for 5 A rated secondary current.

2 · 0.0175 · 50

Rlead

= = 0.3 6

This terminal voltage can be approximately calculated from the IEC data as follows:

R'b = Rlead + Rrelay = 0.3 + 0.1 = 0.4

K'ssc

Rct +Rb Rct + R'b

Kssc

4 + 15 4 + 0.4

43.2

Result: The effective K'ssc is 43.2, the required K'ssc is 25. Therefore the stability criterion is fulfilled.
Relay burden The CT burdens of the numerical relays of Siemens are below 0.1 VA and can therefore be neglected for a practical estimation. Exception is the pilot-wire relay 7SD600.
Intermediate CTs are normally no longer necessary, because the ratio adaptation for busbar protection 7SS52 and transformer protection is numerically performed in the relay.

ANSI CT definition

Us.t.max

Kssc 20

with Rb

Pb Isn2

and

INsn

the

result

Us.t.max

= Pb· Kssc 5 A

Example:

IEC

600 / 5, 5P20, 25 VA,

60044

ANSI

(25 VA · 20)

C57.13:

Us.t.max

5 A

100

acc.

class

C100

15
2/48 Siemens SIP · Edition No. 8

Software for Engineering and Data Evaluation

Page

DIGSI 4 an operating software

for all SIPROTEC protection relays

3/3

IEC 61850 System Configurator

3/5

SIGRA 4 powerful analysis

of all protection fault records

3/7

3/2 Siemens SIP · Edition No. 8

Software for Engineering and Data Evaluation
DIGSI 4 Description

Description

The PC operating program DIGSI 4 is the user interface to all Siemens protection devices, up to and including SIPROTEC 4 and SIPROTEC Compact. It has a simple and intuitive user interface. Using DIGSI 4, the parameters for the SIPROTEC devices are set and evaluated it is the tailor-made program for industrial and energy supply systems.

Functions ·Simple protection settings
The functions actually required can simply be selected from the numerous protection functions. This facilitates increased clarity over the other menus. ·Setting devices with primary and secondary values The settings can be entered and displayed as primary or secondary values. You can switch between primary and secondary values using the mouse click on the toolbar.
Fig. 3/1 DIGSI 4: Main Menu, Selecting the Protection Functions

sc_digsi4_main_menue.tif

Fig. 3/3 CFC Chart
·Commissioning Special attention was paid to commissioning. All binary inputs and outputs can be individually tested and read. This enables an extremely simple wiring check. For test purposes, messages can be intentionally sent to the serial interfaces.
·IEC 61850 System Configurator Using the IEC 61850 system configurator, which is launched from the DIGSI manager, the IEC 61850 network structure and the scope of the data exchange between the participants of an IEC 61850 station can be defined. To do so, subnetworks are added as required to the network working area. These subnetworks are then allocated available participants and the addressing is set. In the GOOSE working area, the data objects between the participants are linked, for example, the pickup indication of the V/AMZ I> function of the feeder 1, which is transmitted to the infeed, in order to effect the reverse interlocking of the V/AMZ I>> function there. For more information, see "IEC 61850 System Configurator Description".

LSP2324-afpen.tif

·Routing matrix The DIGSI 4 matrix shows the user the entire device configuration at a glance. For instance, the allocation of LEDs, binary inputs and standard relays is displayed on one screen. The routing can be changed with the click of a mouse.

sc_digsi4_matrix1.tif

DIGSI 4_IEC 61850.tif

Fig. 3/2 DIGSI 4: Routing Matrix
·CFC: Configure logic instead of programming it Using CFC (Continuous Function Chart), interlockings and switching sequences can be configured, information linked and derived without software expertise simply by drawing technical processes. Logical elements such as AND, OR and timing elements are available, as are limiting value interrogations of measured values.

Fig. 3/4 IEC 61850 System Configurator

Siemens SIP · Edition No. 8 3/3

Software for Engineering and Data Evaluation
DIGSI 4 Selection and Ordering Data

Description
Software for project engineering and operation of Siemens protection devices of the SIPROTEC 4/3/2 and SIPROTEC Compact product families, executable under the following operating systems:
- Microsoft Windows 7 Ultimate, Professional and Enterprise (32/64 Bit)
- Microsoft Windows 10 Professional and Enterprise (64 Bit)
- Microsoft Windows Server 2008/2012 R2 (64 Bit)
See product information for details about the supported service packs of the operating systems.
Including device templates, Comtrade Viewer, electronic help, DIGSI cables (for all devices) and service (update, hotline).
Interface languages: German, English, French, Spanish, Italian, Chinese, Russian, and Turkish (selectable)
Delivery is on DVD-ROM

Variants
Basic Basic version with license for 10 computers (authorization using serial number)
Professional Basic and in addition SIGRA (fault-record analysis), CFC editor (logic editor), display editor (editor for basic and branch control images) and DIGSI 4 remote (remote control) with license for 10 computers (authorization using serial number)
DIGSI 4 Professional + IEC 61850 Professional und zusätzlich IEC 61850 System Confi gurator mit Lizenz für 10 Rechner (Autorisierung per Seriennummer)
Upgrade from DIGSI 4 basic to DIGSI 4 professional
Upgrade from DIGSI 4 basic to DIGSI 4 professional + IEC 61850
Upgrade from DIGSI 4 professional to DIGSI 4 professional + IEC 61850
DIGSI 4 Trial Like DIGSI 4 professional + IEC 61850, but only valid for 30 days (test version, no authorization necessary)
DIGSI 4 scientific Like DIGSI 4 professional + IEC 61850, only for scientific equipment (university, technical college, research institution) with license for 10 computers (authorization using serial number)
DIGSI 4 DVD copy Contains latest DIGSI 4, IEC 61850 system configurator and SIGRA, without license

Order no. 7 X S 5 4 0 0 - 0 A A 0 0
7 X S 5 4 0 2 - 0 A A 0 0
7 X S 5 4 0 3 - 0 A A 0 0
7 X S 5 4 0 7 - 0 A A 0 0 7 X S 5 4 0 8 - 0 A A 0 0 7 X S 5 4 6 0 - 0 A A 0 0 7 X S 5 4 0 1 - 1 A A 0 0
7 X S 5 4 0 2 - 2 A A 0 0
7 X S 5 4 9 0 - 0 A A 0 0

Table 1 DIGSI 4 Selection and Ordering Data

3/4 Siemens SIP · Edition No. 8.1

Software for Engineering and Data Evaluation
IEC 61850 System Configurator Description

Description
The IEC 61850 system configurator is the manufacturer-independent solution for the interoperable engineering of IEC 61850 products and systems. It supports all devices with IEC 61850, not just Siemens products like SIPROTEC 5, SIPROTEC 4, SIPROTEC Compact, Reyrolle, SICAM RTUs, SICAM IO/AI/P85x/ Q100 but also devices from other Siemens divisions (such as SITRAS PRO) or from third parties.
The tool supports SCL configuration files (substation configuration language) from the IEC 61850-6 through import or export of all formats (ICD/IID/CID/SCD/SSD/SED). Thus, IEC 61850 devices can be added and a complete IEC 61850 station is available for substation automation technology.

IEDs from the IEC 61850 standard of Edition 1 or Edition 2 are supported. The possible engineering therefore includes not only GOOSE communication and client/server configuration via MMS reporting, but also system topology, process bus communication with SMV (sampled measured values) and IEC 60870-5-104 addresses for the gateway to the network control center via IEC 61850-80-1.
Simple engineering thanks to customer-friendly workflows and universal display of IEC 61850 addresses as well as customer description texts. Users with IEC 61850 basic or expert knowledge find the desired level of detail.

Fig. 3/5 An IEC 61850 System Configurator for All Devices in the Station

Siemens SIP · Edition No. 8 3/5

Software for Engineering and Data Evaluation
IEC 61850 System Configurator Selection and Ordering Data

Description
IEC 61850 System Configurator
Software for configuring stations with IEC 61850 communication Executable under 32-bit and 64-bit MS Windows 7 Ultimate, Enterprise and Professional/MS Windows 8.1/MS Windows Server 2012 R2 64-bit/MS Windows 10 Professional and Enterprise (64 Bit)
See product information for supported service packs of the operating systems including electronic help and service (update, hotline)
Interface languages: German, English, French, Spanish, Italian, Portuguese, Chinese, Russian and Turkish selectable Supplied on DVD-ROM.

Variants
Stand-alone
For configuration independent from manufacturers of a plant with IEC 61850 devices (SIPROTEC, Reyrolle and devices from the competition), installation independent from DIGSI, with license for 10 computers (authorization using serial number)

Table 2 SIGRA Selection and Ordering Data

Order no. 7XS5461-0A A00

3/6 Siemens SIP · Edition No. 8

Software for Engineering and Data Evaluation
SIGRA Description

Description

The SIGRA user program supports you in analyzing failures in your electrical power system. It graphically analyzes data recorded during the failure and calculates additional supplemental quantities such as impedances, powers or RMS values, from the supplied measured values, making evaluation of the fault record easier for you.
The quantities can be shown as desired in the diagrams of the views
· Time signals
· Phasor diagrams
· Locus diagrams
· Harmonics
· Fault locator
and in the "Table" view.
After a system incident, it is especially important to quickly and completely analyze the error, so that the respective measures can be derived immediately from the cause analysis. This will enable the original network status to be recovered and the down time to be reduced to an absolute minimum.
As well as the usual time signal display of the recorded measured quantity, the current version is also set up to display vector, pie and bar charts to show the harmonics and data tables. From the measured values recorded in the fault records, SIGRA 4 calculates further values, for instance missing quantities in the 3-phase electrical power system, impedances, outputs, symmetrical components, etc. Using two measurement cursors, the fault current can be evaluated easily and conveniently. With the aid of SIGRA however, further fault record can also be added. The signals from another fault record (for example, from the opposite end of the line) are added to the current signal pattern using drag and drop.
SIGRA 4 facilitates the display of signals from various fault records in one diagram as well as a fully automated synchronization of these signals on a common time base. As well as the precise determination of the individual factors of the line fault, the fault location is also of particular interest.
A precise determination of the fault location saves time which the user can use for an on-site inspection of the error. This function is also supported by SIGRA 4 using the "offline fault location" function. SIGRA 4 can be used for all fault records in the COMTRADE file format.
The functions and advantages of SIGRA 4 can often only be optimally displayed directly on the product. For this reason, SIGRA 4 is available as a 30-day test version.
Functions · 6 diagram types:
Time-signal representation (standard)
Locus diagram (for example for RX)
Vector diagram (reading of angles)
Bar chart (for example for visualizing harmonics)
Table (with values of several signals at the same point in time)
Fault-location determination (display of fault location)

Fig. 3/6 SIGRA 4
· Calculation of additional values, such as positive-sequence impedances, RMS values, symmetrical components and phasors
· 2 measuring cursors that are synchronized in all views · High-performance panning and zoom functions
(for example, section enlargement) · User-friendly project engineering via drag and drop · Innovative signal routing in a clearly structured matrix · Time-saving user profiles, which can be assigned to individual
relay types or series · Addition of further fault records and synchronization of
multiple fault records with a common time base · Simple documentation through copying of the diagrams for
example, into MS Office programs · Offline fault-location determination · Commenting of fault records, and commenting of individual
measuring points in diagrams and free placement of these comments in diagrams · Application of mathematical operations to signals
Hardware Requirements · Pentium 4 with 1 GHz processor or similar · 1 GB RAM (2 GB recommended) · Graphic display with resolution of 1024 × 768
(1280 × 1024 recommended) · 50 MB available hard disk space · DVD ROM drive · Keyboard and mouse
Software requirements · MS Windows 7 Ultimate, Enterprise and Professional · MS Windows 8.1 Enterprise · MS Windows Server 2008 R2

Siemens SIP · Edition No. 8 3/7

Software for Engineering and Data Evaluation
SIGRA Selection and Ordering Data

Description
SIGRA Software for graphical visualization, analysis and evaluation of fault records
Executable under 32-bit and 64-bit MS Windows 7 Ultimate, Enterprise and Professional/MS Windows 8.1 Enterprise/MS Windows Server 2008 R2
See product information for supported service packs of the operating systems including sample fault record, electronic help and service (update, hotline)
Interface languages: German, English, French, Spanish, Italian, Chinese, Russian and Turkish, selectable
Incl. Multimedia Tutorial on separate CD-ROM
Supplied on DVD-ROM.

Variants
SIGRA for DIGSI With license for 10 computers (authorization using serial number). The DIGSI 4 license number is required to order.
SIGRA Stand-alone Installation without DIGSI 4 with license for 10 computers (authorization using serial number)
SIGRA Scientific Installation without DIGSI 4 only for scientific equipment (university, technical college, research institution) with license for 10 computers (authorization using serial number)
SIGRA Trial Like SIGRA Stand-alone version but only usable for 30-days (no authorization required)
Upgrade from SIGRA Trial to SIGRA Stand-alone Like SIGRA Stand-alone version for customers who want to activate a trial version with full capabilities and a license for 10 computers

Order no. 7 X S 5 4 1 0 - 0 A A 0 0 7 X S 5 4 1 6 - 0 A A 0 0 7 X S 5 4 1 6 - 1 A A 0 0
7 X S 5 4 1 1 - 1 A A 0 0 7 X S 5 4 1 6 - 2 A A 0 0

Table 3 SIGRA Selection and Ordering Data

3/8 Siemens SIP · Edition No. 8

Communication

Page

Description

4/3

Function overview

4/3

Typical applications

4/5

Integration into substation control systems

4/7

Integration into the SICAM power automation system

4/9

Integration into the substation automation system

4/10

Integration into the SICAM PAS power automation system 4/11

Solution without substation control system

4/12

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
4/2 Siemens SIP · Edition No. 8

Fig. 4/1 Communication structure
Description
Communication interfaces on protection relays are becoming increasingly important for the efficient and economical operation of substations and networks. The interfaces can be used for: ·Accessing the protection relays from a PC using the DIGSI oper-
ating program. Remote access via modem, Ethernet modem is possible with a serial service port at the relay. This allows remote access to all data of the protection relay. ·Integrating the relays into control systems with IEC 608705-103 protocol, PROFIBUS DP protocol, DNP 3.0 protocol, MODBUS protocol, DNP3 TCP, PROFINET and Redundancy protocols for Ethernet (RSTP; PRP and HSR). The standardized IEC 61850 protocol is available since Oct. 2004 and with its SIPROTEC units Siemens has provided this standard as the first manufacturer worldwide. ·Peer-to-peer communication of differential relays and distance relays to exchange real-time protection data via fiber-optic cables, communication network, telephone networks or analog pilot wires.

Communication
Description, function overview

Function overview

Description

·Remote communication with DIGSI

·Remote communication with SIPROTEC

4 units

·Remote communication with SIPROTEC

3 units and SIPROTEC `600 units

Typical applications

·SIPROTEC 4 units on an RS485 bus

·SIPROTEC 4 units with FO/RS485

·Mixed system SIPROTEC 4 ·Configuration with active star-coupler

Integration into substation control systems
5
Integration into the SICAM power automation system

Integration into other systems

15
Siemens SIP · Edition No. 8 4/3

Communication
Description

1 2 3 4 5 6 7 8 9 10 11 12

Description

Remote communication with DIGSI

By using the remote communication functions of DIGSI it is possible to access relays from your office via the telephone network. So you do not have to drive to the substation at all and, if you need to carry out a quick fault analysis, for example, you can transfer the fault data into your office in just a few minutes so that you can use DIGSI to evaluate it.

Another alternative is the ability to access all the units of a substation from a central point within that station. This saves you having to connect your PC individually to all the relays in the station.

In both cases you need a few simple communication units and a PC with DIGSI and a remote communication component installed. The data traffic with DIGSI uses a secure protocol based on the IEC standard similar to IEC 60870-5-103 so that, amongst other things, the relays have unique addresses for accessing purposes.

Fig. 4/2 Remote relay communication

A high level of data integrity is achieved through the check sum incorporated in the telegram. Any telegrams that might become distorted during transmission are repeated. A comparison of parameters between relay and PC to ensure that they match also improves the integrity. There are other security functions too such as passwords and a substation modem callback function which can also be triggered from events.

Since Oct. 2004, a relay can be accessed remotely with DIGSI via an Ethernet interface in the relay and with the IEC 61850 protocol. This allows access to the relays via an Ethernet network. Some relays include a Web server, so an Internet browser can also be used for remote access via Ethernet.

Remote communication with SIPROTEC 4 units
SIPROTEC 4 units are well equipped for remote communication. A separate serial service interface for the protection engineer, independent of the system interface, allows the units to be easily integrated into any communication configuration. The front interface then remains free for local operation. Together with a flexibility in the choice of interface, i.e. optical with an ST connector for multi-mode FO cables or electrical for RS232 or RS485 hard-wired connections, it is easy to create the optimum solution for any particular application.
With SIPROTEC 4 units you can also use PROFIBUS DP to provide a central link with DIGSI via the control system interface. For this you will need a PC with a special PROFIBUS card that must be connected to the PROFIBUS system. This solution is intended exclusively for SIPROTEC 4 units with PROFIBUS DP.

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4/4 Siemens SIP · Edition No. 8

Communication
Typical applications

Typical applications

An extensive range of communication components, such as modems, star couplers, optoelectric converters, prefabricated FO connection cables and electric connection cables (see part 13 of this catalog) allows you to create a variety of different solutions: FO connections immune to interference or cost-effective solutions using the two-wire RS485 electric bus.
The following examples give some indication of what configurations are possible, which items are needed for the purpose and what baud rates are possible.

Example 1: SIPROTEC 4 units on an RS485 bus
Remote communication is effected via a private or public telephone network with both analog or digital telephone lines being possible. An Ethernet network can also be used together with Ethernet modems. The 8N1 data format and an analog baud rate of 57.6/64 kbit/s have become established as the standard for serial modem links. The connection between modem and units is initially optical. An FO/RS485 converter 7XV5650 that can be installed close to the units then converts the signals for the RS485 bus. Up to 31 relays can be connected to the RS485 bus. Particularly in the case of modems, we recommend the use of the types of units listed in part 13.

Fig. 4/3 SIPROTEC 4 units on an RS485 bus (Example 1)

Example 2: SIPROTEC 4 units with FO/RS485
In the case of larger substations with longer distances we recommend the use of FO connection cables. The following example shows a mixed system of optical and electrical connections. Typically, all relays in a cubicle can be linked together via RS485 and the cubicles themselves can be connected to the star coupler via FO cables (see Fig. 4/4).

Fig. 4/4 Two groups of SIPROTEC 4 units on an RS485bus (Example 2)

1 2 3 4 5 6 7 8 9 10 11 12

15
Siemens SIP · Edition No. 8 4/5

Communication
Typical applications

1 2 3 4 5 6 7 8 9 10

Example 3: Mixed system SIPROTEC 4
Relays from different families can be integrated into a remote communication system, as illustrated in Example 3 (see Fig. 4/5). This example also shows how relays can be integrated by means of FO links and star couplers. In this case we recommend to use the 7XV5550 active mini star-coupler (see Fig. 4/6).
Communication will then generally be at 57.6/64 kbit/s on the modem link. For any units that cannot operate at this baud rate the active star-coupler will convert the rate accordingly.

Example 4: Configuration with active star- coupler

With this configuration it is also possible to integrate relays that can only be connected via the front interface and whose maximum baud rates are less than 19.2 kbaud (see Fig. 4/6).

The following points must be noted with

this type of configuration:

Fig. 4/5 Mixed system, FO/RS485 with units from different families (Example 3)

·One output of the active mini star-cou-

pler is used to service several SIPROTEC

4 units through further star couplers or RS485 converters. On that output, a mixed system containing SIPROTEC 3 and series `600 relays should be avoided so that 57600 baud operation is possible for SIPROTEC 4 relays.

The solutions for central and/or remote communication with SIPROTEC units have easy upgrade compatibility. Different versions of relays can be integrated into a remote communication concept. This is supported by the substation and device manage-

·Several SIPROTEC 3 units and series `600 relays can also be

ment in the DIGSI software. A substation can be retrofitted with

connected to another output of the active mini star-coupler

add-on remote communication components provided it has

(via mini star-couplers or RS485 converters). The baud rate for the communication connection available. And changing of the

this output must be set less or equal to 19200 baud.

telephone line from, say, analog to digital does not necessitate

·Relays that are not available with communication functions according to IEC 60870-5-103 protocol (e.g. 7VE51, 7VK51, 7SV51 and older firmware versions of some relays) can also be connected via the active star-coupler as illustrated in Fig. 4/6.

the replacement of all components. Also, Ethernet networks can be used. The telephone modem is then replaced by an Ethernet modem. The infrastructure in the substation remains unchanged.

In this case one output must be assigned to each relay. The

baud rate must be set according to the unit.

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4/6 Siemens SIP · Edition No. 8

Communication
Typical applications, integration into substation control systems

Fig. 4/6 Mixed system with relays from different families, with active star-coupler (Example 4)

Integration into substation control systems
Almost all SIPROTEC units can be integrated into substation control systems via communication interfaces.
The relays can be supplied as part of an integrated Siemens system offering all substation control and protection. In addition, the relays can also be integrated into other control systems via standard protocols. An integrated system offers type-tested functions, consistent con-figuration and optimally coordinated communication protocols. SICAM PAS and SICAM RTUs are proven systems available from Siemens. These systems, also offer Ethernet communication with IEC 61850.
For situations where you would like to integrate SIPROTEC units into other control systems we can offer open communication interfaces. In addition to the IEC 60870-5-103 protocol that is available in almost all relays we can also offer other communication protocols for SIPROTEC 4 units like PROFIBUS DP, MODBUS, DNP 3.0, DNP3 TCP, PROFINET and Redundancy protocols for Ethernet (RSTP;PRP and HSR).

An overview which communication protocols are available in the various SIPROTEC relays can be found in the Internet at www. siemen.com/siprotec or in the catalog "Selection Guide for SIPROTEC and Reyrolle"

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Siemens SIP · Edition No. 8 4/7

Communication
Integration into substation control systems

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

IEC 61850 protocol
Since Oct. 2004, the Ethernet-based IEC 61850 protocol is the worldwide standard for protection and control systems used by power supply corporations, Siemens was the first manufacturer to support the protocol in its devices. By means of this protocol, information can also be exchanged directly between bay units so as to enable the creation of simple masterless systems for bay and system interlocking. Access to the units via the Ethernet bus is also possible with DIGSI.
WebMonitor
It will also be possible to retrieve operating and fault messages and fault recordings via a browser. This Web monitor will also provide a few items of unit specific information in browser windows.
IEC 60870-5-103 protocol
The IEC 60870-5-103 protocol is an international standard for the transmission of protective data and fault recordings. All messages from the unit (and also control commands) can be transferred via published, Siemens-specific extensions.
IEC 60870-5-104 protocol
The IEC 60870-5-104 substation and power system automation protocol is supported via the electrical and optical Ethernet module. Indications (single and double), measured values, metered values can be transmitted to one or two (redundant) masters. IEC 104 file transfer is also supported and fault recordings can be read out of the device in Comtrade format. In the command direction, secured switching of switching objects is possible via the protocol. Time synchronization can be supported via the T104 master or via SNTP across the network.Redundant time servers are supported. All auxiliary services on Ethernet such as the DIGSI 5 protocol, network redundancy, or SNMP for network monitoring can be activated concurrently with T104. Moreover, GOOSE messages of IEC 61850 can be exchanged between devices.
PROFIBUS DP protocol
PROFIBUS DP is the most widespread protocol in industrial automation. Via PROFIBUS DP, SIPROTEC units make their information available to a SIMATIC controller or, in the control direction, receive commands from a central SIMATIC. Measured values can also be transferred. The information is assignable to a mapping file with DIGSI.
Modbus RTU protocol
This uncomplicated, serial protocol is mainly used in industry and by power supply corporations, and is supported by a number of unit vendors. SIPROTEC units behave as MODBUS slaves, making their information available to a master or receiving information from it. Information is assignable to a mapping file with DIGSI.
Protocol Modbus TCP
The Modbus TCP communication protocol is supported by the electrical or optical Ehternet module. Modbus TCP and Modbus RTU are very similar, with Modbus TCP using TCP/IP packets for data transfer. Modbus TCP can be used to transmit indications (single- and double-point indications), measured values, metered measure-

ands to one or two (redundant) masters. Switchgear can be switched in command direction via the protocol. Time synchronization can be implemented via SNTP or IEEE1588 via the network, supporting redundant time servers. All additional services on Ethernet like the DIGSI 5 protocol, network redundany or SNMP for network monitoring can be activated at the same time as Modbus TCP and GOOSE messages of IEC 61850 can be sent over the network between the devices.
Serial DNP3 or DNP3 TCP
DNP 3 is supported as a serial protocol via RS485 or an optical 820 nm interface, and as an Ethernet-based TCP variant via the electrical or optical Ethernet module. In conjunction with Ethernet, the switch integrated in the module can be used such that redundant ring structures for DNP 3 can be realized. In this way, for example, connection to a DNP 3 via a redundant optical Ethernet ring can be established. Information about a device, and the fault records of the device, can be routed and transferred using the DNP 3 protocol. Switching commands can be executed in the control direction.
Redundant connection to 2 serial substation controllers can be established via 2 modules or 1 serial double module. With Ethernet, 2 Ethernet modules that can work independently of one another via 1 or 2 networks are to be provided for a redundant connection. Settings values in the device cannot be read or changed via the protocol.
For DNP 3, the network topologies can also be used for Ethernetbased or serial communication.
PROFINET
PROFINET is the ethernet-based successor of Profibus DP and is supported in the variant PROFINET I/O. The protocol which is used in industry together with the SIMATIC systems control is realized on the optical and electrical Plus ethernet modules which are delivered since November 2012. All network redundancy procedures which are available for the ethernet modules, such as RSTP, PRP or HSR, are also available for PROFINET. The time synchronization is made via SNTP. The network monitoring is possible via SNMP V2 where special MIB files exist for PROFINET. The LLDP protocol of the device also supports the monitoring of the network topology. Single-point indications, double-point indications, measured and metered values can be transmitted cyclically in the monitoring direction via the protocol and can be selected by the user with DIGSI 4. Important events are also transmitted spontaneously via confi gurable process alarms. Switching commands can be executed by the system control via the device in the controlling direction. The PROFINET implementation is certified. The device also supports the IEC 61850 protocol as a server on the same ethernet module in addition to the PROFINET protocol. Client server connections are possible for the intercommunication between devices, e.g. for transmitting fault records and GOOSE messages.
Redundancy protocols for Ethernet (RSTP; PRP and HSR)
The redundancy protocols RSTP, PRP and HSR can be loaded and activated easily via software on the existing optical Ethernet modules. PRP and HSR guarantee a redundant, uninterruptible and seamless data transfer in Ethernet networks without extensive parameter settings in the switches.

4/8 Siemens SIP · Edition No. 8

Communication
Integration into the SICAM power automation system

Substation control port B

Port C

IEC 61850

IEC 60870-5-103 PROFIBUS DP MODBUS

DNP 3.0

DNP3 TCP 4) PROFINET 4) DIGSI

Alarms (relay Æ central unit)

with time stamp

Commands (BC/central unit Æ relay)

Measured values

Time

synchronization

Fault records (sampled values)

Separate port Separate port Separate port (with DIGSI)2) (with DIGSI)2) (with DIGSI)2)

Separate port (with DIGSI)3)

Protection settings

(with DIGSI) Separate port (with DIGSI)3)

Separate port Separate port Separate port Separate port Separate port (with DIGSI)3) (with DIGSI)3) (with DIGSI)3) (with DIGSI)3) (with DIGSI)3)

Parameter group switchover

RSTP/PRP/HSR

1) There is no time synchronization via this protocol. For time synchronization purposes it is possible to use a separate time synchronization interface (Port A in SIPROTEC 4 relays).
2) The transmission of fault records is not part of the protocol. They can be read out with DIGSI via the service interface Port C or the front operating interface.
3) This protocol does not support the transmission of protection settings. Only setting groups can be changed. For this purpose you should use the service interface or the front operating interface together with DIGSI.
4) Only 7SJ61/62/64; 7SJ80/7SK80; 7SC80

Integration into the SICAM power automation system
SIPROTEC 4 is tailor-made for use with the power automation system SICAM. The SICAM family comprises the following components:
·SICAM RTUs, the modern telecontrol systems with automation and programmable logic functions
·SICAM PAS, the substation automation system based on computer hardware
Data management and communication is one of the strong points of the SICAM / SIPROTEC 4 system. Powerful engineering tools make working with SICAM convenient and easy. SIPROTEC 4 units are optimally matched for use in SICAM PAS. With SICAM and SIPROTEC 4 continuity exists at three crucial points:
·Data management
·Software architecture
·Communication
The ability to link SICAM/ SIPROTEC to other substation control, protection and automation components is assured, thanks to open interfaces such as IEC 60870-5-103 protocol and the Ethernet-based IEC 61850 protocol. Other protocols like PROFIBUS DP, DNP 3.0, MODBUS, RTU, DNP3 TCP, PROFINET and Redundancy protocols for Ethernet (RSTP;PRP and HSR) are also supported.

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Siemens SIP · Edition No. 8 4/9

Communication
Integration into substation automation system

SIPROTEC 4 is tailor-made for use with

the SICAM substation automation system. Over the low-cost electrical RS485 bus,

the units exchange information with

the control system. Units featuring

IEC 60870-5-103 interfaces can be

connected to SICAM interference free and radially by fiber-optic link. Through this

interface, the system is open for the con-

nection of units of other manufacturers.

Fig. 4/7 Communication structure with substation automation system

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4/10 Siemens SIP · Edition No. 8

Communication
Integration into the SICAM PAS power automation system

Integration into the SICAM PAS power

automation system

SIPROTEC 4 is tailor-made for use with

the SICAM power automation system

together with IEC 61850 protocol. Via the 100 Mbit/s Ethernet bus, the units

are linked electrically or optically to the

station PC with PAS. Connection may be

simple or redundant. The interface is

standardized, thus also enabling direct

connection of units of other manufactur-

ers to the Ethernet bus. Units featuring an

IEC 60870-5-103 interface or other serial

protocols are connected via the Ethernet station bus to SICAM PAS by means of

serial/Ethernet converters (see Fig. 4/8).

DIGSI and the Web monitor can also be

used over the same station bus. Together with Ethernet/IEC 61850, an

interference-free optical solution is also

provided (see Fig. 4/9). The Ethernet

interface in the relay includes an Ethernet switch. Thus, the installation of expensive

external Ethernet switches can be

avoided. The relays are linked in an

optical ring structure. Integrated SNMP (Simple Network

Fig. 4/8 Ethernet-based system with SICAM PAS with electrical Ethernet interface

Management Protocol) facility allows

the supervision of the network from the

station controller.

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Siemens SIP · Edition No. 8 4/11

Communication
Integration into a substation automation system, solution without substation control system

Integration into a substation auto-

mation system of other makes

Thanks to the standardized interfaces,

IEC 61850, IEC 60870-5-103, DNP3.0,

MODBUS, PROFIBUS DP, SIPROTEC units can also be integrated into non-Siemens

systems or in SIMATIC S5/S7. Electrical

RS485 or optical interfaces are available.

The optimum physical data transfer

medium can be chosen thanks to opto-

electrical converters. Thus, the RS485 bus

allows low-cost wiring in the cubicles and

an interference-free optical connection to

the master can be established.

Fig. 4/9 Ethernet-based system with SICAM PAS with optical Ethernet interface

7 8 9 10 11 12 13

Solution without substation control system
Ethernet-based communication with optical Ethernet interface between SIPROTEC protection relays offers also many advantages without substation control: ·Fast remote access via DIGSI 4 ·High-speed setting and parameteriza-
tion with DIGSI 4 ·Interlocking between different field
devices and exchange of binary signals via GOOSE messages of IEC 61850 ·Common time synchronization of all relays from central time synchronization server (eg. SICLOCK)
For automation of new substations (or plants) and modernization of existing substations you get future investment security, without additional investment.
Fig. 4/10 Ethernet-based system with optical Ethernet interface and migration of relays with serial protocol

15
4/12 Siemens SIP · Edition No. 8

Overcurrent Protection
SIPROTEC 7SJ61 multifunction protection relay SIPROTEC 7SJ62 multifunction protection relay SIPROTEC 7SJ64 multifunction protection relay with synchronization SIPROTEC 7SJ66 multifunction protection relay with local control

Page 5/3 5/25 5/53 5/87
5

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5/2 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ61
SIPROTEC 7SJ61 multifunction protection relay

LSP2299-afpen.eps SIPV6_116.eps

Fig. 5/1 SIPROTEC 7SJ61 multifunction protection relay with text (left) and graphic display

Description
The SIPROTEC 7SJ61 relays can be used for line protection of high and medium voltage networks with earthed (grounded), low-resistance grounded, isolated or compensated neutral point. When protecting motors, the SIPROTEC 7SJ61 is suitable for asynchronous machines of all sizes. The relay performs all functions of backup protection supplementary to transformer differential protection.
The relay provides control of the circuit-breaker, further switching devices and automation functions. The integrated programmable logic (CFC) allows the user to implement their own functions, e. g. for the automation of switchgear (interlocking). The user is also allowed to generate user-defined indications.
The flexible communication interfaces are open for modern communication architectures with control systems.
Function overview
Protection functions · Overcurrent protection
(definite-time/inverse-time/user-def.) · Sensitive ground-fault detection · Intermittent ground-fault protection · High-impedance restricted ground fault · Inrush-current detection · Motor protection
Undercurrent monitoring Starting time supervision Restart inhibit Locked rotor Load jam protection · Overload protection · Temperature monitoring

· Breaker failure protection · Negative-sequence protection · Auto-reclosure · Lockout
Control functions/programmable logic · Commands for control of a circuit-breaker and of isolators · Position of switching elements is shown on the graphic
display · Control via keyboard, binary inputs, DIGSI 4 or SCADA system · User-defined logic with CFC (e.g. interlocking)
Monitoring functions · Operational measured values I · Circuit-breaker wear monitoring · Slave pointer · Time metering of operating hours · Trip circuit supervision · 8 oscillographic fault records · Motor statistics
Communication interfaces · System interface
IEC 60870-5-103, IEC 61850 PROFIBUS DP DNP 3/ DNP3 TCP/MODBUS RTU PROFINET · Service interface for DIGSI 4 (modem) · Front interface for DIGSI 4 · Time synchronization via IRIG B/DCF77
Hardware
· 4 current transformers · 3/8/11 binary inputs · 4/8/6 output relays

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Siemens SIP · Edition No. 8 5/3

Overcurrent Protection/7SJ61
Application

LSA2959-egpen.eps

8 9 10 11 12 13 14 15

Fig. 5/2 Function diagram

Application
The SIPROTEC 7SJ61 unit is a numerical protection relay that also performs control and monitoring functions and therefore supports the user in cost-effective power system management, and ensures reliable supply of electric power to the customers. Local operation has been designed according to ergonomic criteria. A large, easy-to-read display was a major design aim.
Control
The integrated control function permits control of disconnect devices, grounding switches or circuit-breakers via the integrated operator panel, binary inputs, DIGSI 4 or the control and protection system (e.g. SICAM). The present status (or position) of the primary equipment can be displayed, in case of devices with graphic display. A full range of command processing functions is provided.
Programmable logic
The integrated logic characteristics (CFC) allow the user to implement their own functions for automation of switchgear (interlocking) or a substation via a graphic user interface. The user can also generate user-defined indications.
Line protection
The relay is a non-directional overcurrent relay which can be used for line protection of high and medium-voltage networks with earthed (grounded), low-resistance grounded, isolated or compensated neutral point.

Motor protection When protecting motors, the 7SJ61 relay is suitable for asynchronous machines of all sizes.
Transformer protection The relay performs all functions of backup protection supplementary to transformer differential protection. The inrush suppression effectively prevents tripping by inrush currents.
The high-impedance restricted ground-fault protection detects short-circuits and insulation faults on the transformer.
Backup protection The 7SJ61can be used universally for backup protection.
Flexible protection functions By configuring a connection between a standard protection logic and any measured or derived quantity, the functional scope of the relays can be easily expanded by up to 20 protection stages or protection functions.
Metering values Extensive measured values, limit values and metered values permit improved system management.

5/4 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ61
Application, construction

ANSI

IEC

Protection functions

50, 50N

I>, I>>, I>>> IE>, IE>>

Definite-time overcurrent protection (phase/neutral)

50, 51N

Ip, IEp

Inverse-time overcurrent protection (phase/neutral)

50Ns, 51Ns

IEE>, IEE>>, IEEp

Sensitive ground-fault protection

Cold load pick-up (dynamic setting change)

IE>

Intermittent ground fault

87N

High-impedance restricted ground-fault protection

50BF 79

Breaker failure protection Auto-reclosure

I2>

Phase-balance current protection (negative-sequence protection)

Thermal overload protection

Starting time supervision

51M

Load jam protection

Locked rotor protection

66/86

Restart inhibit

Undercurrent monitoring

Temperature monitoring via external device (RTD-box),

e.g. bearing temperature monitoring

Construction
Connection techniques and housing with many advantages -rack size (text display variants) and ½-rack size (graphic display variants) are the available housing widths of the 7SJ61 relays referred to a 19" module frame system. This means that previous models can always be replaced. The height is a uniform 244 mm for flush-mounting housings and 266 mm for surface-mounting housing. All cables can be connected with or without ring lugs. In the case of surface mounting on a panel, the connection terminals are located above and below in the form of screw-type terminals. The communication interfaces are located in a sloped case at the top and bottom of the housing.
Fig. 5/3 Rear view with screw-type, -rack size

LSP2099-afpen.eps

9 10 11 12 13 14

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Siemens SIP · Edition No. 8 5/5

Overcurrent Protection/7SJ61
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13

Protection functions

Overcurrent protection (ANSI 50, 50N, 51, 51N)
This function is based on the phaseselective measurement of the three phase currents and the ground current (four transformers). Three definite-time overcurrent protection elements (DMT) exist both for the phases and for the ground. The current threshold and the delay time can be set within a wide range. In addition, inverse-time overcurrent protection characteristics (IDMTL) can be activated.

Reset characteristics

For easier time coordination with electromechanical relays, reset characteristics according to ANSI C37.112 and IEC 60255-3 / BS 142 standards are applied. When using the reset characteristic (disk emulation), a reset process is initiated after the fault current has disappeared. This reset process corresponds to the reverse movement of the Ferraris disk of an electromechanical relay (thus: disk emulation).
User-definable characteristics

Fig. 5/4 Definite-time overcurrent characteristic
Available inverse-time characteristics Characteristics acc. to Inverse Short inverse Long inverse Moderately inverse Very inverse Extremely inverse

Fig. 5/5 Inverse-time overcurrent characteristic

ANSI/IEEE · · · · · ·

IEC 60255-3 ·
·
· ·

Instead of the predefined time characteristics according to ANSI, tripping characteristics can be defined by the user for phase and ground units separately. Up to 20 current/ time value pairs may be programmed. They are set as pairs of numbers or graphically in DIGSI 4.
Inrush restraint
The relay features second harmonic restraint. If the second harmonic is detected during transformer energization, pickup of non-directional normal elements (I>, Ip) are blocked.
Cold load pickup/dynamic setting change
For overcurrent protection functions the initiation thresholds and tripping times can be switched via binary inputs or by time control.

Flexible protection functions
The 7SJ61 units enable the user to easily add on up to 20 protective functions. To this end, parameter definitions are used to link a standard protection logic with any chosen characteristic quantity (measured or derived quantity). The standard logic consists of the usual protection elements such as the pickup message, the parameter- definable delay time, the TRIP command, a blocking possibility, etc. The mode of operation for current quantities can be three-phase or single-phase. The quantities can be operated as greater than or less than stages. All stages operate with protection priority. Protection stages/functions attainable on the basis of the available characteristic quantities:

Function

ANSI No.

I>, IE>

50, 50N

3I0>, I1>, I2>, I2/I1>

50N, 46

Binary input

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5/6 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ61
Protection functions

(Sensitive) ground-fault detection (ANSI 50Ns, 51Ns/50N, 51N)
For high-resistance grounded networks, a sensitive input transformer is connected to a phase-balance neutral current transformer (also called core-balance CT).
The function can also be operated in the insensitive mode as an additional short-circuit protection.
Intermittent ground-fault protection
Intermittent (re-striking) faults occur due to insulation weaknesses in cables or as a result of water penetrating cable joints. Such faults either simply cease at some stage or develop into lasting short-circuits. During intermittent activity, however, star-point resistors in networks that are impedance-grounded may undergo thermal overloading. The normal ground-fault protection cannot reliably detect and interrupt the current pulses, some of which can be very brief. The selectivity required with intermittent ground faults is achieved by summating the duration of the individual pulses and by triggering when a (settable) summed time is reached. The response threshold IIE> evaluates the r.m.s. value, referred to one systems period.
Breaker failure protection (ANSI 50BF)
If a faulted portion of the electrical circuit is not disconnected upon issuance of a trip command, another command can be initiated using the breaker failure protection which operates the circuit-breaker, e.g. of an upstream (higher-level) protection relay. Breaker failure is detected if after a trip command, current is still flowing in the faulted circuit. As an option it is possible to make use of the circuit-breaker position indication.
Phase-balance current protection (ANSI 46) (Negative-sequence protection)
In line protection, the two-element phase-balance current/ negative-sequence protection permits detection on the high side of high-resistance phase-to-phase faults and phase-to-ground faults that are on the low side of a transformer (e.g. with the switch group Dy 5). This provides backup protection for highresistance faults beyond the transformer.
Settable dropout delay times
If the devices are used in parallel with electromechanical relays in networks with intermittent faults, the long dropout times of the electromechanical devices (several hundred milliseconds) can lead to problems in terms of time grading. Clean time grading is only possible if the dropout time is approximately the same. This is why the parameter of dropout times can be defined for certain functions such as overcurrent protection, ground short-circuit and phase-balance current protection.
Auto-reclosure (ANSI 79)
Multiple reclosures can be defined by the user and lockout will occur if a fault is present after the last reclosure. The following functions are possible: · 3-pole ARC for all types of faults · Separate settings for phase and ground faults · Multiple ARC, one rapid auto-reclosure (RAR) and up to nine
delayed auto-reclosures (DAR) · Starting of the ARC depends on the trip command selection (e.g.
46, 50, 51) · Blocking option of the ARC via binary inputs · ARC can be initiated externally or via CFC

· The overcurrent elements can either be blocked or operated non-delayed depending on the auto-reclosure cycle
· Dynamic setting change of the overcurrent elements can be activated depending on the ready AR

Thermal overload protection (ANSI 49)
For protecting cables and transformers, an overload protection with an integrated pre-warning element for temperature and current can be applied. The temperature is calculated using a thermal homogeneous-body model (according to IEC 60255-8), which takes account both of the energy entering the equipment and the energy losses. The calculated temperature is constantly adjusted accordingly. Thus, account is taken of the previous load and the load fluctuations.
For thermal protection of motors (especially the stator) a further time constant can be set so that the thermal ratios can be detected correctly while the motor is rotating and when it is stopped. The ambient temperature or the temperature of the coolant can be detected serially via an external temperature monitoring box (resistance-temperature detector box, also called RTD-box). The thermal replica of the overload function is automatically adapted to the ambient conditions. If there is no RTD-box it is assumed that the ambient temperatures are constant.

High-impedance restricted ground-fault protection (ANSI 87N)

The high-impedance measurement principle is an uncomplicated and sensitive method for detecting ground faults, especially on transformers. It can also be applied to motors, generators and reactors when these are operated on an grounded network.

When the high-impedance measurement principle is applied, all current transformers in the protected area are connected in parallel and operated on one common resistor of relatively high R whose voltage is measured (see Fig. 5/6). In the case of 7SJ6 units, the voltage is measured by detecting the current through the (external) resistor R at the sensitive current measurement input IEE. The varistor V serves to limit the voltage in the event of an internal fault. It cuts off the high momentary voltage spikes occurring at transformer saturation. At the same time, this results in smoothing of the voltage without any noteworthy reduction of the average value. If no faults have occurred and in the event of external faults, the system is at equilibrium, and the voltage through the resistor is approximately zero. In the event of internal faults, an imbalance occurs which leads to a voltage and a current flow through the resistor R.

The current transformers must be of the same type and must at least offer a separate core for the high-impedance restricted groundfault protection. They must in particular have the same transformation ratio and an approximately identical knee-point voltage. They should also demonstrate only minimal measuring errors.

Fig. 5/6 High-impedance restricted ground-fault protection

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Overcurrent Protection/7SJ61
Protection functions

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Motor protection

Starting time supervision (ANSI 48)

Starting time supervision protects the motor against long unwanted start-ups that might occur when excessive load torque occurs, excessive voltage drops occur within the motor or if the rotor is locked. Rotor temperature is calculated from measured stator current. The tripping time is calculated according to the following equation:

for I > IMOTOR START

I A I

= Actual current flowing

IMOTOR START = Pickup current to detect a motor start

= Tripping time

Fig. 5/7

= Rated motor starting current

= Tripping time at rated motor starting current

(2 times, for warm and cold motor)

If the trip time is rated according to the above formula, even a prolonged start-up and reduced voltage (and reduced start-up current) will be evaluated correctly. The tripping time is inverse (current dependent).

A binary signal is set by a speed sensor to detect a blocked rotor. An instantaneous tripping is effected.

Temperature monitoring (ANSI 38)
Up to 2 temperature monitoring boxes with a total of 12 measuring sensors can be used for temperature monitoring and detection by the protection relay. The thermal status of motors, generators and transformers can be monitored with this device. Additionally, the temperature of the bearings of rotating machines are monitored for limit value violation. The temperatures are being measured with the help of temperature detectors at various locations of the device to be protected. This data is transmitted to the protection relay via one or two temperature monitoring boxes (see "Accessories", page 5/78).

Phase-balance current protection (ANSI 46) (Negative-sequence protection)
The negative-sequence / phase-balance current protection detects a phase failure or load unbalance due to network asymmetry and protects the rotor from impermissible temperature rise.
Restart inhibit (ANSI 66/86)
If a motor is started up too many times in succession, the rotor can be subject to thermal overload, especially the upper edges of the bars. The rotor temperature is calculated from the stator current. The reclosing lockout only permits start-up of the motor if the rotor has sufficient thermal reserves for a complete start-up (see Fig. 5/7).
Emergency start-up
This function disables the reclosing lockout via a binary input by storing the state of the thermal replica as long as the binary input is active. It is also possible to reset the thermal replica to zero.
Undercurrent monitoring (ANSI 37)
With this function, a sudden drop in current, that can occur due to a reduced motor load, is detected. This may be due to shaft breakage, no-load operation of pumps or fan failure.
Motor statistics
Essential information on start-up of the motor (duration, current, voltage) and general information on number of starts, total operating time, total down time, etc. are saved as statistics in the device.
Circuit-breaker wear monitoring
Methods for determining circuit-breaker contact wear or the remaining service life of a circuit-breaker (CB) allow CB maintenance intervals to be aligned to their actual degree of wear. The benefit lies in reduced maintenance costs.
There is no mathematically exact method of calculating the wear or the remaining service life of circuit-breakers that takes into account the arc-chamber's physical conditions when the CB opens.

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Overcurrent Protection/7SJ61
Protection functions

This is why various methods of determining CB wear have evolved which reflect the different operator philosophies. To do justice to these, the devices offer several methods:
· I · Ix, with x = 1... 3 · i2t

The devices additionally offer a new method for determining the remaining service life:
· Two-point method

The CB manufacturers double-logarithmic switching cycle diagram (see Fig. 5/8) and the breaking current at the time of contact opening serve as the basis for this method. After CB opening, the two-point method calculates the number of still possible switching cycles. To this end, the two points P1 and P2 only have to be set on the device. These are specified in the CB's technical data.
All of these methods are phase-selective and a limit value can be set in order to obtain an alarm if the actual value falls below or exceeds the limit value during determination of the remaining service life.

Commissioning
Commissioning could hardly be easier and is fully supported by DIGSI 4. The status of the binary inputs can be read individually and the state of the binary outputs can be set individually. The operation of switching elements (circuit-breakers, disconnect devices) can be checked using the switching functions of the bay controller. The analog measured values are represented as wideranging operational measured values.
To prevent transmission of information to the control center during maintenance, the bay controller communications can be disabled to prevent unnecessary data from being transmitted. During commissioning, all indications with test marking for test purposes can be connected to a control and protection system.
Test operation
During commissioning, all indications can be passed to an automatic control system for test purposes.
Control and automatic functions
Control
In addition to the protection functions, the SIPROTEC 4 units also support all control and monitoring functions that are required for operating medium-voltage or high-voltage substations.
The main application is reliable control of switching and other processes.
The status of primary equipment or auxiliary devices can be obtained from auxiliary contacts and communicated to the 7SJ61 via binary inputs. Therefore it is possible to detect and indicate both the OPEN and CLOSED position or a fault or intermediate circuit-breaker or auxiliary contact position.
The switchgear or circuit-breaker can be controlled via:
integrated operator panel binary inputs substation control and protection system DIGSI 4

Fig. 5/8 CB switching cycle diagram
Automation / user-defined logic
With integrated logic, the user can set, via a graphic interface (CFC), specific functions for the automation of switchgear or substation. Functions are activated via function keys, binary input or via communication interface.
Switching authority
Switching authority is determined according to parameters and communication.
If a source is set to "LOCAL", only local switching operations are possible. The following sequence of switching authority is laid down: "LOCAL"; DIGSI PC program, "REMOTE".
Command processing
All the functionality of command processing is offered. This includes the processing of single and double commands with or without feedback, sophisticated monitoring of the control hardware and software, checking of the external process, control actions using functions such as runtime monitoring and automatic command termination after output. Here are some typical applications: · Single and double commands using 1, 1 plus 1 common or
2 trip contacts · User-definable bay interlocks · Operating sequences combining several switching operations
such as control of circuit-breakers, disconnectors and grounding switches · Triggering of switching operations, indications or alarm by combination with existing information

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Overcurrent Protection/7SJ61
Functions

1 2 3 4 5 6 7 8 9 10 11 12

Functions

Chatter disable
Chatter disable feature evaluates whether, in a configured period of time, the number of status changes of indication input exceeds a specified figure. If exceeded, the indication input is blocked for a certain period, so that the event list will not record excessive operations.

LSP2077f.eps

Indication filtering and delay
Binary indications can be filtered or delayed.
Filtering serves to suppress brief changes in potential at the indication input. The indication is passed on only if the indication voltage is still present after a set period of time. In the event of indication delay, there is a wait for a preset time. The information is passed on only if the indication voltage is still present after this time.

Indication derivation
A further indication (or a command) can be derived from an existing indication. Group indications can also be formed. The volume of information to the system interface can thus be reduced and restricted to the most important signals.
Measured values
The r.m.s. values are calculated from the acquired current. The following functions are available for measured value processing: · Currents IL1, IL2, IL3, IE, IEE (50Ns) · Symmetrical components I1, I2, 3I0 · Mean as well as minimum and maximum current values · Operating hours counter · Mean operating temperature of overload function · Limit value monitoring
Limit values are monitored using programmable logic in the CFC. Commands can be derived from this limit value indication. · Zero suppression In a certain range of very low measured values, the value is set to zero to suppress interference.

Fig. 5/9 NXAIR panel (air-insulated)
Metered values If an external meter with a metering pulse output is available, the SIPROTEC 4 unit can obtain and process metering pulses via an indication input. The metered values can be displayed and passed on to a control center as an accumulation with reset.
Switchgear cubicles for high/medium voltage All units are designed specifically to meet the requirements of high/medium-voltage applications. In general, no separate measuring instruments or additional control components are necessary.

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Overcurrent Protection/7SJ61
Communication

Communication

In terms of communication, the units offer substantial flexibility in the context of connection to industrial and power automation standards. Communication can be extended or added on thanks to modules for retrofitting on which the common protocols run. Therefore, also in the future it will be possible to optimally integrate units into the changing communication infrastructure, for example in Ethernet networks (which will also be used increasingly in the power supply sector in the years to come).

Serial front interface
There is a serial RS232 interface on the front of all the units. All of the unit's functions can be set on a PC by means of the DIGSI 4 protection operation program. Commissioning tools and fault analysis are also built into the program and are available through this interface.
Rear-mounted interfaces1)
A number of communication modules suitable for various applications can be fitted in the rear of the flush-mounting housing. In the flush-mounting housing, the modules can be easily replaced by the user.
The interface modules support the following applications:
· Time synchronization interface All units feature a permanently integrated electrical time synchronization interface. It can be used to feed timing telegrams in IRIG-B or DCF77 format into the units via time synchronization receivers.
· System interface Communication with a central control system takes place through this interface. Radial or ring type station bus topologies can be configured depending on the chosen interface. Furthermore, the units can exchange data through this interface via Ethernet and IEC 61850 protocol and can also be operated by DIGSI.
· Service interface The service interface was conceived for remote access to a number of protection units via DIGSI. On all units, it can be an electrical RS232/RS485 or an optical interface. For special applications, a maximum of two temperature monitoring boxes (RTD-box) can be connected to this interface as an alternative.
System interface protocols (retrofittable)

Fig. 5/10 IEC 60870-5-103: Radial fiber-optic connection
Fig. 5/11 Bus structure for station bus with Ethernet and IEC 61850, fiber-optic ring
from the unit and also control commands can be transferred by means of published, Siemens-specific extensions to the protocol. Redundant solutions are also possible. Optionally it is possible to read out and alter individual parameters (only possible with the redundant module).

1 2 3 4 5 6 7 8 9 10 11

IEC 61850 protocol
The Ethernet-based IEC 61850 protocol is the worldwide standard for protection and control systems used by power supply corporations. Siemens was the first manufacturer to support this standard. By means of this protocol, information can also be exchanged directly between bay units so as to set up simple masterless systems for bay and system interlocking. Access to the units via the Ethernet bus is also possible with DIGSI.
IEC 60870-5-103 protocol
The IEC 60870-5-103 protocol is an international standard for the transmission of protective data and fault recordings. All messages
1) F or units in panel surface-mounting housings please refer to note on page 5/77.

PROFIBUS DP protocol
PROFIBUS DP is the most widespread protocol in industrial automation. Via PROFIBUS DP, SIPROTEC units make their information available to a SIMATIC controller or, in the control direction, receive commands from a central SIMATIC. Measured values can also be transferred.
MODBUS RTU protocol
This uncomplicated, serial protocol is mainly used in industry and by power supply corporations, and is supported by a number of unit manufacturers. SIPROTEC units function as MODBUS slaves, making their information available to a master or receiving information from it. A time-stamped event list is available.

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Overcurrent Protection/7SJ61
Communication

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

PROFINET
PROFINET is the ethernet-based successor of PROFIBUS DP and is supported in the variant PROFINET IO. The protocol which is used in industry together with the SIMATIC systems control is realized on the optical and electrical Plus ethernet modules which are delivered since November 2012. All network redundancy procedures which are available for the ethernet modules, such as RSTP, PRP or HSR, are also available for PROFINET. The time synchronization is made via SNTP. The network monitoring is possible via SNMP V2 where special MIB files exist for PROFINET. The LLDP protocol of the device also supports the monitoring of the network topology. Single-point indications, double-point indications, measured and metered values can be transmitted cyclically in the monitoring direction via the protocol and can be selected by the user with DIGSI 4. Important events are also transmitted spontaneously via configurable process alarms. Switching commands can be executed by the system control via the device in the controlling direction. The PROFINET implementation is certifi ed. The device also supports the IEC 61850 protocol as a server on the same ethernet module in addition to the PROFINET protocol. Client server connections are possible for the intercommunication between devices, e.g. for transmitting fault records and GOOSE messages.

Fig. 5/12 System solution/communication

LSP3.01-0021.tif

DNP 3.0
Power utilities use the serial DNP 3.0 (Distributed Network Protocol) for the station and network control levels. SIPROTEC units function as DNP slaves, supplying their information to a master system or receiving information from it.

Fig. 5/13 Optical Ethernet communication module for IEC 61850 with integrated Ethernet-switch

DNP3 TCP
The ethernet-based TCP variant of the DNP3 protocol is supported with the electrical and optical ethernet module. Two DNP3 TCP clients are supported. Redundant ring structures can be realized for DNP3 TCP with the help of the integrated switch in the module. For instance, a redundant optical ethernet ring can be constructed. Single-point indications, double-point indications, measured and metered values can be configured with DIGSI 4 and are transmitted to the DNP3 TCP client. Switching commands can be executed in the controlling direction. Fault records of the device are stored in the binary Comtrade format and can be retrieved via the DNP3 file transfer. The time synchronization is performed via the DNP3 TCP client or SNTP. The device can also be integrated into a network monitoring system via the SNMP V2 protocol. Parallel to the DNP3 TCP protocol the IEC 61850 protocol (the device works as a server) and the GOOSE messages of the IEC 61850 are available for the intercommunication between devices.

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Overcurrent Protection/7SJ61
Typical connections

For IEC 61850, an interoperable system solution is offered with

SICAM PAS. Via the 100 Mbits/s Ethernet bus, the units are linked with PAS electrically or optically to the station PC. The interface

is standardized, thus also enabling direct connection of units of

other manufacturers to the Ethernet bus. With IEC 61850, how-

ever, the units can also be used in other manufacturers' systems

(see Fig. 5/11).

Typical connections

Connection of current

and voltage transformers

Standard connection

For grounded networks, the ground current

is obtained from the phase currents by the

residual current circuit.
5

Fig. 5/14 Residual current circuit

Fig. 5/15 Sensitive ground current detection

12 13

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Overcurrent Protection/7SJ61
Typical applications

Overview of connection types

Type of network

(Low-resistance) grounded network

(Low-resistance) grounded networks

Isolated or compensated networks

Isolated networks

Compensated networks

Function Overcurrent protection hase/ground non-directional
Sensitive ground-fault protection
Overcurrent protection phases non-directional
Sensitive ground-fault protection
Sensitive ground-fault protection

Current connection Residual circuit, with 3 phase-current transformers required, phase-balance neutral current transformer possible Phase-balance neutral current transformers required Residual circuit, with 3 or 2 phase current transformers possible
Phase-balance neutral current transformers required Phase-balance neutral current transformers required

Typical applications

Trip circuit supervision (ANSI 74TC)

One or two binary inputs can be used for monitoring the circuit-breaker trip coil

including its incoming cables. An alarm

signal occurs whenever the circuit is

interrupted.

8
Fig. 5/16 Trip circuit supervision with 2 binary inputs
9

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5/14 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ61
Technical data

General unit data

Measuring circuits

System frequency

50 / 60 Hz (settable)

Current transformer

Rated current Inom
Option: sensitive ground-fault CT
Power consumption at Inom = 1 A at Inom = 5 A for sensitive ground-fault CT at 1 A

1 or 5 A (settable) IEE < 1.6 A
Approx. 0.05 VA per phase Approx. 0.3 VA per phase Approx. 0.05 VA

Overload capability Thermal (effective)
Dynamic (impulse current)

500 A for 1 s 150 A for 10 s 20 A continuous 250 x Inom (half cycle)

Overload capability if equipped with

sensitive ground-fault CT

Thermal (effective)

300 A for 1 s

100 A for 10 s

15 A continuous

Dynamic (impulse current)

750 A (half cycle)

Auxiliary voltage (via integrated converter)

Rated auxiliary voltage Vaux
Permissible tolerance

DC 24/48 V 60/125 V 110/250 V

115/230 V

DC 19-58 V 48-150 V 88-330 V

92-138 V 184-265 V

Ripple voltage, peak-to-peak 12 %

Power consumption Quiescent Energized

Approx. 3 W Approx. 7 W

Backup time during loss/short-circuit of auxiliary voltage

50 ms at V DC 110 V 20 ms at V DC 24 V 200 ms at AC 115 V/230 V

Binary inputs/indication inputs

Type

7SJ610

7SJ611, 7SJ613

7SJ612, 7SJ614

Number

Voltage range

DC 24250 V

Pickup threshold

Modifiable by plug-in jumpers

Pickup threshold

DC 19 V

88 V

For rated control voltage DC 24/48/60/110/125 V 110/220/250 V

Response time/ drop-out time

Approx. 3.5 ms

Power consumption energized

1.8 mA (independent of operating voltage)

Binary outputs/command outputs

Type

7SJ610, 7SJ611, 7SJ613 7SJ612, 7SJ614

Number command/indication relay 4

Contacts per command/ indication relay

1 NO / form A (2 contacts changeable to NC/form B, via jumpers)

Live status contact

1 NO / NC (jumper) / form A / B

Switching capacity Make

1000 W/VA

Switching voltage Permissible current

Break

30 W/VA / 40 Wresistive / 25 W at L/R 50 ms

DC 250 V

5 A continuous, 30 A for 0.5 s making current, 2000 switching cycles

Electrical tests

Specification

Standards

IEC 60255 ANSI C37.90, C37.90.1, C37.90.2, UL508

Insulation tests

Standards

IEC 60255-5; ANSI/IEEE C37.90.0

Voltage test (100 % test) all circuits except for auxiliary voltage and RS485/RS232 and time synchronization

2.5 kV (r.m.s. value), 50/60 Hz

Auxiliary voltage

DC 3.5 kV

Communication ports and time synchronization

AC 500 V

Impulse voltage test (type test) 5 kV (peak value); 1.2/50 µs; 0.5 J all circuits, except communication 3 positive and 3 negative impulses ports and time synchronization, at intervals of 5 s class III

EMC tests for interference immunity; type tests

Standards

IEC 60255-6; IEC 60255-22 (product standard) EN 50082-2 (generic specification) DIN 57435 Part 303

High-frequency test IEC 60255-22-1, class III and VDE 0435 Part 303, class III

2.5 kV (peak value); 1 MHz; =15 ms; 400 surges per s; test duration 2 s

Electrostatic discharge IEC 60255-22-2 class IV and EN 61000-4-2, class IV
Irradiation with radio-frequency field, non-modulated IEC 60255-22-3 (Report) class III

8 kV contact discharge; 15 kV air gap discharge; both polarities; 150 pF; Ri = 330
10 V/m; 27 to 500 MHz

Irradiation with radio-frequency field, amplitude-modulated IEC 61000-4-3; class III

10 V/m, 80 to 1000 MHz; AM 80 %; 1 kHz

Irradiation with radio-frequency 10 V/m, 900 MHz; repetition

field, pulse-modulated

rate 200 Hz, on duration 50 %

IEC 61000-4-3/ENV 50204; class III

Fast transient interference/burst IEC 60255-22-4 and IEC 61000-4-4, class IV
High-energy surge voltages (Surge) IEC 61000-4-5; class III Auxiliary voltage

4 kV; 5/50 ns; 5 kHz; burst length = 15 ms; repetition rate 300 ms; both polarities; Ri = 50 ; test duration 1 min
From circuit to circuit: 2 kV; 12 ; 9 µF across contacts: 1 kV; 2 ;18 µF

Binary inputs/outputs

From circuit to circuit: 2 kV; 42 ; 0.5 µF across contacts: 1 kV; 42 ; 0.5 µF

Line-conducted HF, amplitude-modulated IEC 61000-4-6, class III

10 V; 150 kHz to 80 MHz; AM 80 %; 1 kHz

Power frequency magnetic field IEC 61000-4-8, class IV IEC 60255-6

30 A/m; 50 Hz, continuous 300 A/m; 50 Hz, 3 s 0.5 mT, 50 Hz

Oscillatory surge withstand capability ANSI/IEEE C37.90.1

2.5 to 3 kV (peak value), 1 to 1.5 MHz damped wave; 50 surges per s; duration 2 s, Ri = 150 to 200

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Overcurrent Protection/7SJ61
Technical data

1 2 3 4 5 6 7 8 9 10 11 12 13

EMC tests for interference immunity; type tests (cont'd)

Fast transient surge withstand capability ANSI/IEEE C37.90.1
Radiated electromagnetic interference ANSI/IEEE C37.90.2

4 to 5 kV; 10/150 ns; 50 surges per s both polarities; duration 2 s, Ri = 80
35 V/m; 25 to 1000 MHz; amplitude and pulse-modulated

Damped wave IEC 60694 / IEC 61000-4-12

2.5 kV (peak value, polarity alternating) 100 kHz, 1 MHz, 10 and 50 MHz, Ri = 200

EMC tests for interference emission; type tests

Standard

EN 50081-* (generic specification)

Conducted interferences

150 kHz to 30 MHz

only auxiliary voltage IEC/CISPR 22 Limit class B

Radio interference field strength 30 to 1000 MHz

IEC/CISPR 11

Limit class B

Units with a detached operator panel must be installed in a metal cubicle to maintain limit class B

Mechanical stress tests

Vibration, shock stress and seismic vibration

During operation

Standards

IEC 60255-21 and IEC 60068-2

Vibration IEC 60255-21-1, class 2 IEC 60068-2-6

Sinusoidal 10 to 60 Hz; ± 0.075 mm amplitude; 60 to 150 Hz; 1 g acceleration frequency sweep 1 octave/min 20 cycles in 3 perpendicular axes

Shock IEC 60255-21-2, class 1 IEC 60068-2-27

Semi-sinusoidal Acceleration 5 g, duration 11 ms; 3 shocks in both directions of 3 axes

Seismic vibration IEC 60255-21-3, class 1 IEC 60068-3-3

During transportation

Standards

IEC 60255-21 and IEC 60068-2

Vibration IEC 60255-21-1, class 2 IEC 60068-2-6

Sinusoidal 5 to 8 Hz: ± 7.5 mm amplitude; 8 to 150 Hz; 2 g acceleration, frequency sweep 1 octave/min 20 cycles in 3 perpendicular axes

Shock IEC 60255-21-2, Class 1 IEC 60068-2-27

Semi-sinusoidal Acceleration 15 g, duration 11 ms 3 shocks in both directions of 3 axes

Continuous shock IEC 60255-21-2, class 1 IEC 60068-2-29

Semi-sinusoidal Acceleration 10 g, duration 16 ms 1000 shocks in both directions of 3 axes

Climatic stress tests

Temperatures

Type-tested acc. to IEC 60068-2-1 -25 °C to +85 °C /-13 °F to +185 °F and -2, test Bd, for 16 h

Temporarily permissible operating -20 °C to +70 °C /-4 °F to -158 °F temperature, tested for 96 h

Recommended permanent operating temperature acc. to IEC 60255-6 (Legibility of display may be impaired above +55 °C /+131 °F) Limiting temperature during
permanent storage Limiting temperature during
transport

-5 °C to +55 °C /+25 °F to +131 °F
-25 °C to +55 °C /-13 °F to +131 °F -25 °C to +70 °C /-13 °F to +158 °F

Humidity

Permissible humidity

Annual average 75 % relative

It is recommended to arrange the humidity; on 56 days a year up to

units in such a way that they are 95 % relative humidity;

not exposed to direct sunlight or condensation not permissible!

pronounced temperature changes

that could cause condensation.

Unit design

Housing

7XP20

Dimensions

See dimension drawings, part 14

Weight 1/3 19'', surface-mounting housing 4.5 kg 1/3 19'', flush-mounting housing 4.0 kg 1/2 19'', surface-mounting housing 7.5 kg 1/2 19'', flush-mounting housing 6.5 kg

Degree of protection acc. to EN 60529 Surface-mounting housing Flush-mounting housing Operator safety

IP 51 Front: IP 51, rear: IP 20; IP 2x with cover

Futher information can be found in the current manual at: www.siemens.com/siprotec

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5/16 Siemens SIP · Edition No. 8

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Selection and ordering data

Description 7SJ61multifunction protection relay
Housing, binary inputs (BI) and outputs (BO) Housing 19", 4 line text display, 3 BI, 4 BO, 1 live status contact Housing 19", 4 line text display, 8 BI, 8 BO, 1 live status contact Housing 19", 4 line text display, 11 BI, 6 BO, 1 live status contact Housing ½19", graphic display, 8 BI, 8 BO, 1 live status contact 7) Housing ½19", graphic display, 11 BI, 6 BO, 1 live status contact 7)
Measuring inputs (4 x I) Iph =1A1), Ie =1A1) (min. = 0.05 A) Position 15 only with A Iph =1A1), Ie = sensitive (min. = 0.001 A) Position 15 only with B Iph =5A1), Ie =5A1) (min. = 0.25 A) Position 15 only with A Iph =5A1), Ie = sensitive (min. = 0.001 A) Position 15 only with B Iph =5A1), Ie =1A1) (min. = 0.05 A) Position 15 only with A
Rated auxiliary voltage (power supply, indication voltage) DC 24 to 48 V, threshold binary input DC 19 V 3) DC 60 to 125 V 2), threshold binary input DC 19 V 3) DC 110 to 250 V 2), AC 115 to 230 V4) , threshold binary input DC 88 V 3) DC 110 to 250 V 2), AC 115 to 230 V4) , threshold binary input DC 176 V 3)
Unit version For panel surface mounting, 2 tier terminal top/bottom For panel flush mounting, plug-in terminal (2/3 pin connector) For panel flush mounting, screw-type terminal (direct connection/ring-type cable lugs)
Region-specific default settings/function versions and language settings Region DE, 50 Hz, IEC, language: German, selectable Region World, 50/60 Hz, IEC/ANSI, language: English (GB), selectable Region US, 60 Hz, ANSI, language: English (US), selectable Region FR, 50/60 Hz, IEC/ANSI, language: French, selectable Region World, 50/60 Hz, IEC/ANSI, language: Spanish, selectable Region IT, 50/60 Hz, IEC/ANSI, language: Italian, selectable
System interface (Port B): Refer to page 5/77 No system interface Protocols see page 5/77
Service interface (Port C) No interface at rear side DIGSI 4/modem, electrical RS232 DIGSI 4/modem/RTD-box5), electrical RS485 DIGSI 4/modem/RTD-box5)6), optical 820 nm wavelength, ST connector
Measuring/fault recording Fault recording Slave pointer,mean values, min/max values, fault recording

Order No. 7SJ61 - -
0 1 2 3 4
1 2 5
6
7
2 4 5 6
B D E
A B C D E F
0
0 1 2 3
1 3

1 2 3 4 5 6 7 8 9 10 11 12 13

1) Rated current can be selected by means of jumpers.
2) T ransition between the two auxiliary voltage ranges can be selected by means of jumpers.
3) T he binary input thresholds can be selected per binary input by means of jumpers.
4) A C 230 V, starting from device version .../EE.

5) T emperature monitoring box 7XV5662- AD10, refer to "Accessories".
6) When using the temperature monitoring box at an optical interface, the additional RS485 fiber-optic converter 7XV5650-0 A00 is required.
7) s tarting from device version .../GG and FW-Version V4.82

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Overcurrent Protection/7SJ61
Selection and ordering data

1 2 3 4 5 6 7 8 9 10 11

Description 7SJ61multifunction protection relay

Designation ANSI No. Description

Basic version

50/51 50N/51N 50N/51N

50/50N

49 46
50BF 37 74TC

Control
Overcurrent protection I>, I>>, I>>>, Ip Ground-fault protection IE>, IE>>, IE>>>, IEp Ground-fault protection via insensitive IEE function: IEE>, IEE>>, IEEp1) Flexible protection functions (index quantities derived from current): Additional time-overcurrent protection stages I2>, I>>>>, IE>>>> Overload protection (with 2 time constants) Phase balance current protection (negative-sequence protection) Breaker failure protection Undercurrent monitoring Trip circuit supervision 4 setting groups, cold-load pickup Inrush blocking Lockout

IEF

Intermittent ground fault

50Ns/51Ns Sensitive ground-fault detection (non-directional)

87N

High-impedance restricted ground fault

IEF 50Ns/51Ns Sensitive ground-fault detection (non-directional)

87N

High-impedance restricted ground fault

Intermittent ground fault

Motor IEF

50Ns/51Ns 87N
48/14 66/86 51M

Sensitive ground-fault detection (non-directional) High-impedance restricted ground fault Intermittent ground fault Starting time supervision, locked rotor Restart inhibit Load jam protection, motor statistics

Motor

50Ns/51Ns 87N 48/14 66/86 51M

Sensitive ground-fault detection (non-directional) High-impedance restricted ground fault Starting time supervision, locked rotor Restart inhibit Load jam protection, motor statistics

Motor

48/14 66/86 51M

Starting time supervision, locked rotor Restart inhibit Load jam protection, motor statistics

ARC

Without

With auto-reclosure

14 15

Basic version included IEF = Intermittent ground fault 1) 50N/51N only with insensitive ground-current transformer
when position 7 = 1, 5, 7. 2) Sensitive ground-current transformer only when position 7 = 2, 6.

5/18 Siemens SIP · Edition No. 8

Order No.

Order code

7SJ61 - -

F A P A F B 2) P B 2)
R B 2)
H B 2) H A
0 1

Overcurrent Protection/7SJ61
Selection and ordering data

Description 7SJ61multifunction protection relay System interface (on rear of unit, Port B)

Order No.

Order code

7SJ61 - - -

No system interface

IEC 60870-5-103 protocol, RS232

IEC 60870-5-103 protocol, RS485

IEC 60870-5-103 protocol, 820 nm fiber, ST connector

PROFIBUS DP Slave, RS485

PROFIBUS DP Slave, 820 nm wavelength, double ring, ST connector 1)

MODBUS, RS485

MODBUS, 820 nm wavelength, ST connector 2)

DNP 3.0, RS485

DNP 3.0, 820 nm wavelength, ST connector 2)

IEC 60870-5-103 protocol, redundant, RS485, RJ45 connector 2)

IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector (EN 100)

IEC 61850, 100 Mbit Ethernet, optical, double, LC connector (EN 100) 2)

DNP3 TCP + IEC 61850, 100Mbit Eth, electrical, double, RJ45 connector 3)

DNP3 TCP + IEC 61850, 100Mbit Eth, optical, double, LC connector 3)

PROFINET + IEC 61850, 100Mbit Eth, electrical, double, RJ45 connector 3)

PROFINET + IEC 61850, 100Mbit Eth, optical, double, RJ45 connector 3)

1) Not with position 9 = "B"; if 9 = "B", please order 7SJ6 unit with RS485 port and separate fiber-optic converters. For single ring, please order converter 6GK1502-3AB10, not available with position 9 = "B". For double ring, please order converter 6GK1502-4AB10, not available with position 9 = "B". The converter requires a AC 24 V power supply (e.g. power supply 7XV5810-0BA00).
2) Not available with position 9 = "B".
3) Available with V4.9

L 0 A

L 0 B L 0 D

L 0 E

L 0 G

L 0 H

L 0 P

L 0 R

L 0 S

L 2 R

L 2 S

L 3 R

L 3 S
6

Sample order
Position
6 I/O's: 11 BI/6 BO, 1 live status contact 7 Current transformer: 5 A 8 Power supply: DC 110 to 250 V, AC 115 V to AC 230 V 9 Unit version: Flush-mounting housing, screw-type terminals 10 Region: US, English language (US); 60 Hz, ANSI 11 Communication: System interface: DNP 3.0, RS485 12 Communication: DIGSI 4, electric RS232 13 Measuring/fault recording: Extended measuring and fault records 14/15 Protection function package: Basic version 16 With auto-reclosure

Order No. + Order code 7SJ612 5 - 5 E C 9 1 - 3 F A 1 + L 0 G

5 E

L 0 G

F A

9 10 11 12 13

15
Siemens SIP · Edition No. 8 5/19

Overcurrent Protection/7SJ61
Selection and ordering data

Accessories
1 2 3 4 5 6

Description
Temperature monitoring box AC/DC 24 to 60 V AC/DC 90 to 240 V
Varistor/Voltage Arrester Voltage arrester for high-impedance REF protection 125 Vrms; 600 A; 1S/S 256 240 Vrms; 600 A; 1S/S 1088
Connecting cable Cable between PC/notebook (9-pin con.) and protection unit (9-pin connector) (contained in DIGSI 4, but can be ordered additionally) Cable between temperature monitoring box and SIPROTEC 4 unit - length 5 m/16.4 ft - length 25 m/82 ft - length 50 m/164 ft
Manual for 7SJ61 English/German

Order No.
7XV5662-2AD10 7XV5662-5AD10
C53207-A401-D76-1 C53207-A401-D77-1
7XV5100-4
7XV5103-7AA05 7XV5103-7AA25 7XV5103-7AA50 C53000-G1140-C210-x 1)

8 1) x = please inquire for latest edition (exact Order No.).
9

15
5/20 Siemens SIP · Edition No. 8

LSP2289-afp.eps

Accessories Mounting rail

LSP2091-afp.eps

LSP2090-afp.eps

2-pin connector

3-pin connector

LSP2092-afp.eps

LSP2093-afp.eps

Short-circuit links

for current terminals for current terminals

Overcurrent Protection/7SJ61
Selection and ordering data

Description Terminal safety cover

Order No.

Size of

Supplier

package

Voltage/current terminal 18-pole/12-pole C73334-A1-C31-1

Siemens

Voltage/current terminal 12-pole/8-pole

C73334-A1-C32-1

Connector 2-pin

C73334-A1-C35-1

Connector 3-pin

C73334-A1-C36-1

Siemens

Crimp connector CI2 0.5 to 1 mm2

0-827039-1

4000

Crimp connector CI2 0.5 to 1 mm2

0-827396-1

taped on reel

Crimp connector: Type III+ 0.75 to 1.5 mm2 0-163084-2

Crimp connector: Type III+ 0.75 to 1.5 mm2 0-163083-7

4000

Crimping tool for Type III+

taped on reel

0-539635-1

and matching female

0-539668-2

Crimping tool for CI2

0-734372-1

and matching female

1-734387-1

Short-circuit links

for current terminals for other terminals
Mounting rail for 19" rack

C73334-A1-C33-1

C73334-A1-C34-1

C73165-A63-D200-1 1

Siemens

1) Your local Siemens representative can inform you on local suppliers.
7

15
Siemens SIP · Edition No. 8 5/21

Overcurrent Protection/7SJ61
Connection diagram

14 15

5/22 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ61
Connection diagram

7SJ611, 7SJ613

7SJ611x-x B xxx-xxxx

7SJ613x-x B xxx-xxxx 7SJ611x-x D xxx-xxxx

7SJ613x-x D xxx-xxxx

LSA2820-dgpen.eps

14 15
Siemens SIP · Edition No. 8 5/23

Overcurrent Protection/7SJ61
Connection diagram

14 15

5/24 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ62
SIPROTEC 7SJ62 multifunction protection relay

Fig. 5/20 Multifunction protection relay with text (left) and graphic display

LSP2299-afpen.eps SIPV6_116.eps

Protection functions (continued)

· Inrush restraint · Motor protection

· Overload protection

· Temperature monitoring

· Under-/overvoltage protection

· Under-/overfrequency protection

· Rate-of-frequency-change protection

· Power protection (e.g. reverse, factor) · Undervoltage controlled reactive power

protection

· Breaker failure protection

· Negative-sequence protection

· Phase-sequence monitoring

· Synchro-check

· Fault locator · Lockout

· Auto-reclosure

Description
The SIPROTEC 7SJ62 relays can be used for line protection of high and medium voltage networks with earthed (grounded), low-resistance grounded, isolated or compensated neutral point. With regard to motor protection, the SIPROTEC 7SJ62 is suitable for asynchronous machines of all sizes. The relay performs all functions of backup protection supplementary to transformer differential protection.
7SJ62 is featuring the "flexible protection functions". Up to 20 protection functions can be added according to individual requirements. Thus, for example, a rate-of-frequency-change protection or reverse power protection can be implemented.
The relay provides control of the circuit-breaker, further switching devices and automation functions. The integrated programmable logic (CFC) allows the user to implement their own functions, e. g. for the automation of switchgear (interlocking). The user is also allowed to generate user-defined messages.
The flexible communication interfaces are open for modern communication architectures with control systems.
Function overview
Protection functions · Overcurrent protection · Directional overcurrent protection · Sensitive directional ground-fault detection · Displacement voltage · Intermittent ground-fault protection · Directional intermittent ground fault protection · High-impedance restricted ground fault

Control functions/programmable logic · Commands f. ctrl of CB and of isolators · Position of switching elements is shown on the graphic
display · Control via keyboard, binary inputs, DIGSI 4 or SCADA system · User-defined logic with CFC (e.g. interlocking)
Monitoring functions · Operational measured values V, I, f · Energy metering values Wp, Wq · Circuit-breaker wear monitoring · Slave pointer · Trip circuit supervision · Fuse failure monitor · 8 oscillographic fault records · Motor statistics
Communication interfaces · System interface
IEC 60870-5-103/IEC 61850 PROFIBUS DP DNP 3/DNP3 TCP/MODBUS RTU PROFINET · Service interface for DIGSI 4 (modem) · Front interface for DIGSI 4 · Time synchronization via IRIG B/DCF77
Hardware
· 4 current transformers · 3/4 voltage transformers · 8/11 binary inputs · 8/6 output relays

6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 5/25

Overcurrent Protection/7SJ62
Application

LSA2958-egpen.eps

8 9 10 11 12 13 14 15

Fig. 5/21 Function diagram

Application
The SIPROTEC 7SJ62 unit is a numerical protection relay that also performs control and monitoring functions and therefore supports the user in cost-effective power system management, and ensures reliable supply of electric power to the customers. Local operation has been designed according to ergonomic criteria. A large, easy-to-read display was a major design aim.
Control
The integrated control function permits control of disconnect devices, grounding switches or circuit-breakers via the integrated operator panel, binary inputs, DIGSI 4 or the control and protection system (e.g. SICAM). The present status (or position) of the primary equipment can be displayed, in case of devices with graphic display. A full range of command processing functions is provided.
Programmable logic
The integrated logic characteristics (CFC) allow the user to implement their own functions for automation of switchgear (interlocking) or a substation via a graphic user interface. The user can also generate user-defined messages.
Line protection
The 7SJ62 units can be used for line protection of high and medium-voltage networks with earthed (grounded), lowresistance grounded, isolated or compensated neutral point.

Synchro-check
In order to connect two components of a power system, the relay provides a synchro-check function which verifies that switching ON does not endanger the stability of the power system.
Motor protection
When protecting motors, the 7SJ62 relay is suitable for asynchronous machines of all sizes.
Transformer protection
The relay performs all functions of backup protection supplementary to transformer differential protection. The inrush suppression effectively prevents tripping by inrush currents. The high-impedance restricted ground-fault protection detects short-circuits and insulation faults on the transformer.
Backup protection
The 7SJ62 can be used universally for backup protection.
Flexible protection functions
By configuring a connection between a standard protection logic and any measured or derived quantity, the functional scope of the relays can be easily expanded by up to 20 protection stages or protection functions.
Metering values
Extensive measured values, limit values and metered values permit improved system management.

5/26 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ62
Application

ANSI 50, 50N 50, 51V, 51N 67, 67N
67Ns/50Ns 59N/64
67Ns 87N 50BF 79 25 46 47 49 48 51M 14 66/86 37 38 27, 59 59R 32 27/Q 55 81O/U 81R
21FL

IEC

Protection functions

I>, I>>, I>>>, IE>, IE>>,IE>>> Definite-time overcurrent protection (phase/neutral)

Ip, IEp

Inverse overcurrent protection (phase/neutral), phase function with voltage-dependent option

Idir>, Idir>>, Ip dir IEdir>, IEdir>>, IEp dir
IEE>, IEE>>, IEEp

Directional overcurrent protection (definite/inverse, phase/neutral), Directional comparison protection
Directional/non-directional sensitive ground-fault detection

Cold load pick-up (dynamic setting change)

VE, V0>

Displacement voltage, zero-sequence voltage

IIE> IIE dir>

Intermittent ground fault Directional intermittent ground fault protection

High-impedance restricted ground-fault protection

Breaker failure protection Auto-reclosure

Synchro-check

I2>

Phase-balance current protection (negative-sequence protection)

V2>, phase-sequence

Unbalance-voltage protection and/or phase-sequence monitoring

Thermal overload protection

Starting time supervision

Load jam protection

Locked rotor protection

Restart inhibit

Undercurrent monitoring

Temperature monitoring via external device (RTD-box), e.g. bearing temperature monitoring

V<, V> dV/dt P<>, Q<>

Undervoltage/overvoltage protection Rate-of-voltage-change protection Reverse-power, forward-power protection

Q>/V< cos

Undervoltage-controlled reactive power protection Power factor protection

f>, f< df/dt

Overfrequency/underfrequency protection Rate-of-frequency-change protection

Fault locator

1 2 3 4 5 6 7 8 9 10 11 12

15
Siemens SIP · Edition No. 8 5/27

Overcurrent Protection/7SJ62
Construction, protection functions

LSP2099-afpen.eps

Fig. 5/22 Rear view with screw-type

terminals, 1/3-rack size

Fig. 5/23 Definite-time overcurrent protection Fig. 5/24 Inverse-time overcurrent protection

6 7 8 9 10 11 12 13 14

Construction
Connection techniques and housing with many advantages
1/3-rack size (text display variants) and 1/2-rack size (graphic display variants) are the available housing widths of the 7SJ62 relays, referred to a 19" module frame system. This means that previous models can always be replaced. The height is a uniform 244 mm for flush-mounting housings and 266 mm for surfacemounting housing. All cables can be connected with or without ring lugs.
In the case of surface mounting on a panel, the connection terminals are located above and below in the form of screw-type terminals. The communication interfaces are located in a sloped case at the top and bottom of the housing.
Protection functions
Overcurrent protection (ANSI 50, 50N, 51, 51V, 51N)
This function is based on the phase-selective measurement of the three phase currents and the ground current (four transformers). Three definite-time overcurrent protection elements (DMT) exist both for the phases and for the ground. The current threshold and the delay time can be set within a wide range. In addition, inverse-time overcurrent protection characteristics (IDMTL) can be activated. The inverse-time function provides as an option voltagerestraint or voltage-controlled operating modes.

Available inverse-time characteristics

Characteristics acc. to

ANSI/IEEE

Inverse

Short inverse

Long inverse

Moderately inverse

Very inverse

Extremely inverse

IEC 60255-3 ·
·
· ·

Reset characteristics
For easier time coordination with electromechanical relays, reset characteristics according to ANSI C37.112 and IEC 60255-3 / BS 142 standards are applied.
When using the reset characteristic (disk emulation), a reset process is initiated after the fault current has disappeared. This reset process corresponds to the reverse movement of the Ferraris disk of an electromechanical relay (thus: disk emulation).
User-definable characteristics
Instead of the predefined time characteristics according to ANSI, tripping characteristics can be defined by the user for phase and ground units separately. Up to 20 current/time value pairs may be programmed. They are set as pairs of numbers or graphically in DIGSI 4.
Inrush restraint
The relay features second harmonic restraint. If the second harmonic is detected during transformer energization, pickup of non-directional and directional normal elements are blocked.

Cold load pickup/dynamic setting change
For directional and non-directional overcurrent protection functions the initiation thresholds and tripping times can be switched via binary inputs or by time control.

5/28 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ62
Protection functions

Directional overcurrent protection (ANSI 67, 67N)
Directional phase and ground protection are separate functions. They operate in parallel to the non-directional overcurrent elements. Their pickup values and delay times can be set separately. Definite-time and inverse-time characteristics are offered. The tripping characteristic can be rotated about ± 180 degrees.
By means of voltage memory, directionality can be determined reliably even for close-in (local) faults. If the switching device closes onto a fault and the voltage is too low to determine direction, directionality (directional decision) is made with voltage from the voltage memory. If no voltage exists in the memory, tripping occurs according to the coordination schedule.
For ground protection, users can choose whether the direction is to be determined via zero-sequence system or negativesequence system quantities (selectable). Using negativesequence variables can be advantageous in cases where the zero voltage tends to be very low due to unfavorable zero-sequence impedances.

Fig. 5/25 Directional characteristic of the directional overcurrent protection

Directional comparison protection (cross-coupling)
It is used for selective protection of sections fed from two sources with instantaneous tripping, i.e. without the disadvantage of time coordination. The directional comparison protection is suitable if the distances between the protection stations are not significant and pilot wires are available for signal transmission. In addition to the directional comparison protection, the directional coordinated overcurrent protection is used for complete selective backup protection. If operated in a closed-circuit connection, an interruption of the transmission line is detected.

(Sensitive) directional ground-fault detection (ANSI 64, 67Ns, 67N)
For isolated-neutral and compensated networks, the direction of power flow in the zero sequence is calculated from the zerosequence current I0 and zero-sequence voltage V0.
For networks with an isolated neutral, the reactive current component is evaluated; for compensated networks, the active current component or residual resistive current is evaluated. For special network conditions, e.g. high-resistance grounded networks with ohmic-capacitive ground-fault current or lowresistance grounded networks with ohmic-inductive current, the tripping characteristics can be rotated approximately ± 45 degrees.
Two modes of ground-fault direction detection can be implemented: tripping or "signalling only mode".
It has the following functions:
· TRIP via the displacement voltage VE. · Two instantaneous elements or one instantaneous plus one
user-defined characteristic.
· Each element can be set in forward, reverse, or nondirectional.
· The function can also be operated in the insensitive mode as an additional short-circuit protection.

Fig. 5/26 Directional determination using cosine measurements for compensated networks
(Sensitive) ground-fault detection (ANSI 50Ns, 51Ns / 50N, 51N) For high-resistance grounded networks, a sensitive input transformer is connected to a phase-balance neutral current transformer (also called core-balance CT). The function can also be operated in the insensitive mode as an additional short-circuit protection.

1 2 3 4 5 6 7 8 9 10 11 12 13 14

15
Siemens SIP · Edition No. 8 5/29

Overcurrent Protection/7SJ62
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Intermittent ground-fault protection
Intermittent (re-striking) faults occur due to insulation weaknesses in cables or as a result of water penetrating cable joints. Such faults either simply cease at some stage or develop into lasting short-circuits. During intermittent activity, however, star-point resistors in networks that are impedance-grounded may undergo thermal overloading. The normal ground-fault protection cannot reliably detect and interrupt the current pulses, some of which can be very brief. The selectivity required with intermittent ground faults is achieved by summating the duration of the individual pulses and by triggering when a (settable) summed time is reached. The response threshold IIE> evaluates the r.m.s. value, referred to one systems period.

Directional intermittent ground fault protection (ANSI 67Ns)
The directional intermittent ground fault protection has to detect intermittent ground faults in resonant grounded cable systems selectively. Intermittent ground faults in resonant grounded cable systems are usually characterized by the following properties:
· A very short high-current ground current pulse (up to several hundred amperes) with a duration of under 1 ms
· They are self-extinguishing and re-ignite within one halfperiod up to several periods, depending on the power system conditions and the fault characteristic.
· Over longer periods (many seconds to minutes), they can develop into static faults.
Such intermittent ground faults are frequently caused by weak insulation, e.g. due to decreased water resistance of old cables. Ground fault functions based on fundamental component measured values are primarily designed to detect static ground faults and do not always behave correctly in case of intermittent ground faults. The function described here evaluates specifi cally the ground current pulses and puts them into relation with the zero-sequence voltage to determine the direction.
Phase-balance current protection (ANSI 46) (Negative-sequence protection)
In line protection, the two-element phase-balance current/ negative-sequence protection permits detection on the high side of high-resistance phase-to-phase faults and phase-to-ground faults that are on the low side of a transformer (e.g. with the switch group Dy 5). This provides backup protection for highresistance faults beyond the transformer.
Breaker failure protection (ANSI 50BF)
If a faulted portion of the electrical circuit is not disconnected upon issuance of a trip command, another command can be initiated using the breaker failure protection which operates the circuit-breaker, e.g. of an upstream (higher-level) protection relay. Breaker failure is detected if, after a trip command, current is still flowing in the faulted circuit. As an option, it is possible to make use of the circuit-breaker position indication.

Fig. 5/27 High-impedance restricted ground-fault protection
High-impedance restricted ground-fault protection (ANSI 87N)
The high-impedance measurement principle is an uncomplicated and sensitive method for detecting ground faults, especially on transformers. It can also be applied to motors, generators and reactors when these are operated on an grounded network.
When the high-impedance measurement principle is applied, all current transformers in the protected area are connected in parallel and operated on one common resistor of relatively high R whose voltage is measured (see Fig. 5/27). In the case of 7SJ6 units, the voltage is measured by detecting the current through the (external) resistor R at the sensitive current measurement input IEE. The varistor V serves to limit the voltage in the event of an internal fault. It cuts off the high momentary voltage spikes occurring at transformer saturation. At the same time, this results in smoothing of the voltage without any noteworthy reduction of the average value.
If no faults have occurred and in the event of external faults, the system is at equilibrium, and the voltage through the resistor is approximately zero. In the event of internal faults, an imbalance occurs which leads to a voltage and a current flow through the resistor R.
The current transformers must be of the same type and must at least offer a separate core for the high-impedance restricted ground-fault protection. They must in particular have the same transformation ratio and an approximately identical knee-point voltage. They should also demonstrate only minimal measuring errors.

15
5/30 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ62
Protection functions

Flexible protection functions
The 7SJ62 units enable the user to easily add on up to 20 protective functions. To this end, parameter definitions are used to link a standard protection logic with any chosen characteristic quantity (measured or derived quantity) (Fig. 5/28). The standard logic consists of the usual protection elements such as the pickup message, the parameter-definable delay time, the TRIP command, a blocking possibility, etc. The mode of operation for current, voltage, power and power factor quantities can be three-phase or single-phase. Almost all quantities can be operated as greater than or less than stages. All stages operate with protection priority.
Protection stages/functions attainable on the basis of the available characteristic quantities:

Function I>, IE> V<, V>, VE>, dV/dt 3I0>, I1>, I2>, I2/I1, 3V0>, V1><, V2><, Q>< cos (p.f.)>< f><
df/dt><

ANSI No. 50, 50N 27, 59, 59R, 64 50N, 46, 59N, 47 32 55 81O, 81U
81R

For example, the following can be implemented: · Reverse power protection (ANSI 32R) · Rate-of-frequency-change protection (ANSI 81R)
Undervoltage-controlled reactive power protection (ANSI 27/Q)
The undervoltage-controlled reactive power protection protects the system for mains decoupling purposes. To prevent a voltage collapse in energy systems, the generating side, e.g. a generator, must be equipped with voltage and frequency protection devices. An undervoltage-controlled reactive power protection is required at the supply system connection point. It detects critical power system situations and ensures that the power generation facility is disconnected from the mains. Furthermore, it ensures that reconnection only takes place under stable power system conditions. The associated criteria can be parameterized.
Synchro-check (ANSI 25)
In case of switching ON the circuit- breaker, the units can check whether the two subnetworks are synchronized. Voltage-, frequency- and phase-angle-differences are being checked to determine whether synchronous conditions are existent.
Auto-reclosure (ANSI 79)
Multiple reclosures can be defined by the user and lockout will occur if a fault is present after the last reclosure. The following functions are possible: · 3-pole ARC for all types of faults · Separate settings for phase and ground faults · Multiple ARC, one rapid auto-reclosure (RAR) and up to nine
delayed auto-reclosures (DAR)

dv /dt
LSA4113-aen.eps
Fig. 5/28 Flexible protection functions
· Starting of the ARC depends on the trip command selection (e.g. 46, 50, 51, 67)
· Blocking option of the ARC via binary inputs · ARC can be initiated externally or via CFC · The directional and non-directional elements can either be
blocked or operated non-delayed depending on the autoreclosure cycle · Dynamic setting change of the directional and non-directional elements can be activated depending on the ready AR
Thermal overload protection (ANSI 49)
For protecting cables and transformers, an overload protection with an integrated pre-warning element for temperature and current can be applied. The temperature is calculated using a thermal homogeneous-body model (according to IEC 60255-8), which takes account both of the energy entering the equipment and the energy losses. The calculated temperature is constantly adjusted accordingly. Thus, account is taken of the previous load and the load fluctuations.
For thermal protection of motors (especially the stator) a further time constant can be set so that the thermal ratios can be detected correctly while the motor is rotating and when it is stopped. The ambient temperature or the temperature of the coolant can be detected serially via an external temperature monitoring box (resistance-temperature detector box, also called RTD-box). The thermal replica of the overload function is automatically adapted to the ambient conditions. If there is no RTD-box it is assumed that the ambient temperatures are constant.
Settable dropout delay times
If the devices are used in parallel with electromechanical relays in networks with intermittent faults, the long dropout times of the electromechanical devices (several hundred milliseconds) can lead to problems in terms of time grading. Clean time grading is only possible if the dropout time is approximately the same. This is why the parameter of dropout times can be defined for certain functions such as time-over-current protection, ground short-circuit and phase-balance current protection.

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 5/31

Overcurrent Protection/7SJ62
Protection functions

1 2 3 4 5 6 7 8 9 10 11

12 13 14 15

Motor protection

Restart inhibit (ANSI 66/86)
If a motor is started up too many times in succession, the rotor can be subject to thermal overload, especially the upper edges of the bars. The rotor temperature is calculated from the stator current. The reclosing lockout only permits start-up of the motor if the rotor has sufficient thermal reserves for a complete start-up (see Fig. 5/29).

Emergency start-up
This function disables the reclosing lockout via a binary input by storing the state of the thermal replica as long as the binary input is active. It is also possible to reset the thermal replica to zero.

Temperature monitoring (ANSI 38)

Up to two temperature monitoring boxes with a total of 12 measuring sensors

Fig. 5/29

can be used for temperature monitoring

and detection by the protection relay. The thermal status of

motors, generators and transformers can be monitored with this

device. Additionally, the temperature of the bearings of rotating

machines are monitored for limit value violation. The tempera-

tures are being measured with the help of temperature detectors

at various locations of the device to be protected. This data is

transmitted to the protection relay via one or two temperature

monitoring boxes (see "Accessories", page 5/115).

Starting time supervision (ANSI 48/14)
Starting time supervision protects the motor against long unwanted start-ups that might occur in the event of excessive load torque or excessive voltage drops within the motor, or if the rotor is locked. Rotor temperature is calculated from measured stator current. The tripping time is calculated according to the following equation:

for I > IMOTOR START

I A I

= Actual current flowing

IMOTOR START = Pickup current to detect a motor start

= Tripping time

= Rated motor starting current

= Tripping time at rated motor starting current

(2 times, for warm and cold motor)

Load jam protection (ANSI 51M) Sudden high loads can cause slowing down and blocking of the motor and mechanical damages. The rise of current due to a load jam is being monitored by this function (alarm and tripping).
The overload protection function is too slow and therefore not suitable under these circumstances.
Phase-balance current protection (ANSI 46) (Negative-sequence protection) The negative-sequence / phase-balance current protection detects a phase failure or load unbalance due to network asymmetry and protects the rotor from impermissible temperature rise.
Undercurrent monitoring (ANSI 37) With this function, a sudden drop in current, which can occur due to a reduced motor load, is detected. This may be due to shaft breakage, no-load operation of pumps or fan failure.
Motor statistics Essential information on start-up of the motor (duration, current, voltage) and general information on number of starts, total operating time, total down time, etc. are saved as statistics in the device.
Voltage protection
Overvoltage protection (ANSI 59) The two-element overvoltage protection detects unwanted network and machine overvoltage conditions. The function can operate either with phase-to-phase, phase-to-ground, positive phase-sequence or negative phase-sequence system voltage. Three-phase and single-phase connections are possible.
Undervoltage protection (ANSI 27) The two-element undervoltage protection provides protection against dangerous voltage drops (especially for electric machines). Applications include the isolation of generators or motors from the network to avoid undesired operating states and a possible loss of stability. Proper operating conditions of electrical machines are best evaluated with the positivesequence quantities. The protection function is active over a

5/32 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ62
Protection functions

wide frequency range (45 to 55, 55 to 65 Hz)1). Even when

falling below this frequency range the function continues to work, however, with a greater tolerance band.

The function can operate either with phase-to-phase, phase-to-

ground or positive phase-sequence voltage and can be moni-

tored with a current criterion. Three-phase and single-phase

connections are possible.

Frequency protection (ANSI 81O/U)

Frequency protection can be used for over- frequency and under-

frequency protection. Electric machines and parts of the system are protected from unwanted speed deviations. Unwanted

frequency changes in the network can be detected and the load

can be removed at a specified frequency setting.

Frequency protection can be used over a wide frequency range (40 to 60, 50 to 70 Hz)1). There are four elements (select- able

as overfrequency or underfrequency) and each element can be

delayed separately. Blocking of the frequency protection can be

performed if using a binary input or by using an undervoltage element.

Fault locator (ANSI 21FL)

The integrated fault locator calculates the fault impedance and the distance-to-fault. The results are displayed in , kilometers (miles) and in percent of the line length.

Fig. 5/30 CB switching cycle diagram

Circuit-breaker wear monitoring Methods for determining circuit-breaker contact wear or the remaining service life of a circuit-breaker (CB) allow CB maintenance intervals to be aligned to their actual degree of wear. The benefit lies in reduced maintenance costs.
There is no mathematically exact method of calculating the wear or the remaining service life of circuit-breakers that takes into account the arc-chamber's physical conditions when the CB opens. This is why various methods of determining CB wear have evolved which reflect the different operator philosophies. To do justice to these, the devices offer several methods:
· I · Ix, with x = 1... 3 · i2t The devices additionally offer a new method for determining the remaining service life:
· Two-point method
The CB manufacturers double-logarithmic switching cycle diagram (see Fig. 5/30) and the breaking current at the time of contact opening serve as the basis for this method. After CB opening, the two-point method calculates the number of still possible switching cycles. To this end, the two points P1 and P2 only have to be set on the device. These are specified in the CB's technical data.
All of these methods are phase-selective and a limit value can be set in order to obtain an alarm if the actual value falls below or exceeds the limit value during determination of the remaining service life.
Customized functions (ANSI 32, 51V, 55, etc.) Additional functions, which are not time critical, can be implemented via the CFC using measured values. Typical functions include reverse power, voltage controlled overcurrent, phase angle detection, and zero-sequence voltage detection.
1) The 45 to 55, 55 to 65 Hz range is available for fN = 50/60 Hz.

Commissioning
Commissioning could hardly be easier and is fully supported by DIGSI 4. The status of the binary inputs can be read individually and the state of the binary outputs can be set individually. The operation of switching elements (circuit-breakers, disconnect devices) can be checked using the switching functions of the bay controller. The analog measured values are represented as wideranging operational measured values. To prevent transmission of information to the control center during maintenance, the bay controller communications can be disabled to prevent unnecessary data from being transmitted. During commissioning, all indications with test marking for test purposes can be connected to a control and protection system.
Test operation
During commissioning, all indications can be passed to an automatic control system for test purposes.
Control and automatic functions
Control
In addition to the protection functions, the SIPROTEC 4 units also support all control and monitoring functions that are required for operating medium-voltage or high-voltage substations.
The main application is reliable control of switching and other processes.
The status of primary equipment or auxiliary devices can be obtained from auxiliary contacts and communicated to the 7SJ62 via binary inputs. Therefore it is possible to detect and indicate both the OPEN and CLOSED position or a fault or intermediate circuit-breaker or auxiliary contact position.
The switchgear or circuit-breaker can be controlled via: integrated operator panel binary inputs substation control and protection system DIGSI 4

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Siemens SIP · Edition No. 8 5/33

Overcurrent Protection/7SJ62
Functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Automation/user-defined logic With integrated logic, the user can set, via a graphic interface (CFC), specific functions for the automation of switchgear or substation. Functions are activated via function keys, binary input or via communication interface.
Switching authority Switching authority is determined according to parameters and communication.
If a source is set to "LOCAL", only local switching operations are possible. The following sequence of switching authority is laid down: "LOCAL"; DIGSI PC program, "REMOTE".
Command processing All the functionality of command processing is offered. This includes the processing of single and double commands with or without feedback, sophisticated monitoring of the control hardware and software, checking of the external process, control actions using functions such as runtime monitoring and automatic command termination after output. Here are some typical applications:
· Single and double commands using 1, 1 plus 1 common or 2 trip contacts
· User-definable bay interlocks
· Operating sequences combining several switching operations such as control of circuit-breakers, disconnectors and grounding switches
· Triggering of switching operations, indications or alarm by combination with existing information
Assignment of feedback to command The positions of the circuit-breaker or switching devices and transformer taps are acquired by feedback. These indication inputs are logically assigned to the corresponding command outputs. The unit can therefore distinguish whether the indication change is a consequence of switching operation or whether it is a spontaneous change of state.
Chatter disable Chatter disable feature evaluates whether, in a configured period of time, the number of status changes of indication input exceeds a specified figure. If exceeded, the indication input is blocked for a certain period, so that the event list will not record excessive operations.
Indication filtering and delay Binary indications can be filtered or delayed.
Filtering serves to suppress brief changes in potential at the indication input. The indication is passed on only if the indication voltage is still present after a set period of time. In the event of indication delay, there is a wait for a preset time. The information is passed on only if the indication voltage is still present after this time.
Indication derivation A further indication (or a command) can be derived from an existing indication. Group indications can also be formed. The volume of information to the system interface can thus be reduced and restricted to the most important signals.

Fig. 5/31 NXAIR panel (air-insulated)
Switchgear cubicles for high/medium voltage All units are designed specifically to meet the requirements of high/medium-voltage applications. In general, no separate measuring instruments (e.g., for current, voltage, frequency, ...) or additional control components are necessary.
Measured values The r.m.s. values are calculated from the acquired current and voltage along with the power factor, frequency, active and reactive power. The following functions are available for measured value processing: · Currents IL1, IL2, IL3, IE, IEE (67Ns) · Voltages VL1, VL2, VL3, VL1L2, VL2L3, VL3L1 · Symmetrical components I1, I2, 3I0; V1, V2, V0 · Power Watts, Vars, VA/P, Q, S (P, Q: total and phase selective) · Power factor (cos ), (total and phase selective) · Frequency · Energy ± kWh, ± kVarh, forward and reverse power flow · Mean as well as minimum and maximum current and voltage
values · Operating hours counter · Mean operating temperature of overload function · Limit value monitoring
Limit values are monitored using programmable logic in the CFC. Commands can be derived from this limit value indication. · Zero suppression In a certain range of very low measured values, the value is set to zero to suppress interference.

LSP2077f.eps

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Overcurrent Protection/7SJ62
Communication

Communication
In terms of communication, the units offer substantial flexibility in the context of connection to industrial and power automation standards. Communication can be extended or added on thanks to modules for retrofitting on which the common protocols run. Therefore, also in the future it will be possible to optimally integrate units into the changing communication infrastructure, for example in Ethernet networks (which will also be used increasingly in the power supply sector in the years to come).
Serial front interface
There is a serial RS232 interface on the front of all the units. All of the unit's functions can be set on a PC by means of the DIGSI 4 protection operation program. Commissioning tools and fault analysis are also built into the program and are available through this interface.
Rear-mounted interfaces1)
A number of communication modules suitable for various applications can be fitted in the rear of the flush-mounting housing. In the flush-mounting housing, the modules can be easily replaced by the user. The interface modules support the following applications:
· Time synchronization interface All units feature a permanently integrated electrical time synchronization interface. It can be used to feed timing telegrams in IRIG-B or DCF77 format into the units via time synchronization receivers.
· System interface Communication with a central control system takes place through this interface. Radial or ring type station bus topologies can be configured depending on the chosen interface. Furthermore, the units can exchange data through this interface via Ethernet and IEC 61850 protocol and can also be operated by DIGSI.
· Service interface The service interface was conceived for remote access to a number of protection units via DIGSI. On all units, it can be an electrical RS232/RS485 or an optical interface. For special applications, a maximum of two temperature monitoring boxes (RTD-box) can be connected to this interface as an alternative.
System interface protocols (retrofittable)
IEC 61850 protocol
The Ethernet-based IEC 61850 protocol is the worldwide standard for protection and control systems used by power supply corporations. Siemens was the first manufacturer to support this standard. By means of this protocol, information can also be exchanged directly between bay units so as to set up simple masterless systems for bay and system interlocking. Access to the units via the Ethernet bus is also possible with DIGSI.
IEC 60870-5-103 protocol
The IEC 60870-5-103 protocol is an international standard for the transmission of protective data and fault recordings. All messages from the unit and also control commands can be transferred by means of published, Siemens-specific extensions to the protocol.
1) F or units in panel surface-mounting housings please refer to note on page 5/114.

Fig. 5/32 IEC 60870-5-103: Radial fiber-optic connection
Fig. 5/33 Bus structure for station bus with Ethernet and IEC 61850, fiber-optic ring
Redundant solutions are also possible. Optionally it is possible to read out and alter individual parameters (only possible with the redundant module). PROFIBUS DP protocol PROFIBUS DP is the most widespread protocol in industrial automation. Via PROFIBUS DP, SIPROTEC units make their information available to a SIMATIC controller or, in the control direction, receive commands from a central SIMATIC. Measured values can also be transferred. MODBUS RTU protocol This uncomplicated, serial protocol is mainly used in industry and by power supply corporations, and is supported by a number of unit manufacturers. SIPROTEC units function as MODBUS slaves, making their information available to a master or receiving information from it. A time-stamped event list is available.

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Siemens SIP · Edition No. 8 5/35

Overcurrent Protection/7SJ62
Communication

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

PROFINET
PROFINET is the ethernet-based successor of Profi bus DP and is supported in the variant PROFINET IO. The protocol which is used in industry together with the SIMATIC systems control is realized on the optical and electrical Plus ethernet modules which are delivered since November 2012. All network redundancy procedures which are available for the ethernet modules, such as RSTP, PRP or HSR, are also available for PROFINET. The time synchronization is made via SNTP. The network monitoring is possible via SNMP V2 where special MIB files exist for PROFINET. The LLDP protocol of the device also supports the monitoring of the network topology. Single-point indications, double-point indications, measured and metered values can be transmitted cyclically in the monitoring direction via the protocol and can be selected by the user with DIGSI 4. Important events are also transmitted spontaneously via confi gurable process alarms. Switching commands can be executed by the system control via the device in the controlling direction. The PROFINET implementation is certified. The device also supports the IEC 61850 protocol as a server on the same ethernet module in addition to the PROFINET protocol. Client server connections are possible for the intercommunication between devices, e.g. for transmitting fault records and GOOSE messages.

Fig. 5/34 System solution/communication

LSP3.01-0021.tif

Fig. 5/35 Optical Ethernet communication module for IEC 61850 with integrated Ethernet-switch

DNP3 TCP
The ethernet-based TCP variant of the DNP3 protocol is supported with the electrical and optical ethernet module. Two DNP3 TCP clients are supported. Redundant ring structures can be realized for DNP3 TCP with the help of the integrated switch in the module. For instance, a redundant optical ethernet ring can be constructed. Single-point indications, double-point indications, measured and metered values can be configured with DIGSI 4 and are transmitted to the DNPi client. Switching commands can be executed in the controlling direction. Fault records of the device are stored in the binary Comtrade format and can be retrieved via the DNP 3 file transfer. The time synchronization is performed via the DNPi client or SNTP. The device can also be integrated into a network monitoring system via the SNMP V2 protocol. Parallel to the DNP3 TCP protocol the IEC 61850 protocol (the device works as a server) and the GOOSE messages of the IEC 61850 are available for the intercommunication between devices.

5/36 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ62
Typical connections

in the cubicles and an interference-free optical connection to the

master can be established. For IEC 61850, an interoperable system solution is offered with

SICAM PAS. Via the 100 Mbits/s Ethernet bus, the units are linked

with PAS electrically or optically to the station PC. The interface

is standardized, thus also enabling direct connection of units of other manufacturers to the Ethernet bus. With IEC 61850, how-

ever, the units can also be used in other manufacturers' systems

(see Fig. 5/33).

Typical connections

Connection of current and voltage transformers

Standard connection

For grounded networks, the ground current is obtained from the phase currents by the residual current circuit.

Fig. 5/36 Residual current circuit without directional element

Fig. 5/37 Sensitive ground-current detection without directional element

Fig. 5/38 Residual current circuit with directional element

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Overcurrent Protection/7SJ62
Typical connections

Connection for compensated networks

The figure shows the connection of two phase-to-ground voltages and the

VE voltage of the open delta winding

and a phase-balance neutral current

transformer for the ground current. This connection maintains maximum precision

for directional ground-fault detection and

must be used in compensated networks.

Fig. 5/39 shows sensitive directional

ground-fault detection.

Fig. 5/39 Sensitive directional ground-fault detection with directional element for phases

Connection for isolated-neutral or compensated networks only

If directional ground-fault protection is

not used, the connection can be made

with only two phase current transformers. Directional phase short-circuit protection

can be achieved by using only two

primary transformers.

10 11 12

Connection for the synchro-check function
The 3-phase system is connected as reference voltage, i. e. the outgoing voltages as well as a single-phase voltage, in this case a busbar voltage, that has to be checked for synchronism.

Fig. 5/40 Isolated-neutral or compensated networks

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5/38 Siemens SIP · Edition No. 8

Fig. 5/41 Measuring of the busbar voltage and the outgoing feeder voltage for the synchro-check

Overcurrent Protection/7SJ62
Typical applications

Overview of connection types

Type of network

Function

Current connection

Voltage connection

(Low-resistance) grounded network Overcurrent protection

Residual circuit, with 3 phase-current

phase/ground non-directional transformers required, phase-balance

neutral current transformer possible

(Low-resistance) grounded networks Sensitive ground-fault protection Phase-balance neutral current

transformers required

Isolated or compensated networks Overcurrent protection phases Residual circuit, with 3 or 2 phase

non-directional

current transformers possible

(Low-resistance) grounded networks Overcurrent protection

Residual circuit, with 3 phase-current Phase-to-ground connection or

phases directional

transformers possible

phase-to-phase connection

Isolated or compensated networks Overcurrent protection phases directional
(Low-resistance) grounded networks Overcurrent protection ground directional

Isolated networks

Sensitive ground-fault protection

Residual circuit, with 3 or 2 phase-

Phase-to-ground connection or

current transformers possible

phase-to-phase connection

Residual circuit, with 3 phase-current Phase-to-ground connection required

transformers required, phase-balance

neutral current transformers possible

Residual circuit, if ground current

3 times phase-to-ground connection or

> 0.05 IN on secondary side, otherwise phase-to-ground connection with open

phase-balance neutral current

delta winding

transformers required

Compensated networks

Sensitive ground-fault p rotection Phase-balance neutral current

cos measurement

transformers required

Phase-to-ground connection with open delta winding required

Typical applications

Connection of circuit-breaker

Undervoltage releases
Undervoltage releases are used for automatic tripping of high-voltage motors.
Example: DC supply voltage of control system fails and manual electric tripping is no longer possible.
Automatic tripping takes place when voltage across the coil drops below the trip limit. In Fig. 5/42, tripping occurs due to failure of DC supply voltage, by automatic opening of the live status contact upon failure of the protection unit or by shortcircuiting the trip coil in event of network fault.
In Fig. 5/43 tripping is by failure of auxiliary voltage and by interruption of tripping circuit in the event of network failure. Upon failure of the protection unit, the tripping circuit is also interrupted, since contact held by internal logic drops back into open position.

Fig. 5/42 Undervoltage release with make contact (50, 51)

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Fig. 5/43 Undervoltage trip with locking contact (trip signal 50 is inverted)

Siemens SIP · Edition No. 8 5/39

Overcurrent Protection/7SJ62
Typical applications

Trip circuit supervision (ANSI 74TC)

One or two binary inputs can be used for monitoring the circuit-breaker trip coil

including its incoming cables. An alarm

signal occurs whenever the circuit is

interrupted.

Lockout (ANSI 86)

All binary outputs can be stored like LEDs

and reset using the LED reset key. The lockout state is also stored in the event of

supply voltage failure. Reclosure can only

occur after the lockout state is reset.

Reverse-power protection for dual supply (ANSI 32R)

If power is fed to a busbar through two

parallel infeeds, then in the event of any

fault on one of the infeeds it should be

selectively interrupted. This ensures a

Fig. 5/44 Trip circuit supervision with 2 binary inputs

continued supply to the busbar through

the remaining infeed. For this purpose,

directional devices are needed which detect a short-circuit current or a power

flow from the busbar in the direction of

the infeed. The directional overcurrent

protection is usually set via the load current. It cannot be used to deactivate

low-current faults. Reverse-power

protection can be set far below the rated

power. This ensures that it also detects power feedback into the line in the event

of low-current faults with levels far below

the load current.

Reverse-power protection is performed via

the "flexible protection functions" of the 7SJ62.

10 11

Fig. 5/45 Reverse-power protection for dual supply

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5/40 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ62
Technical data

General unit data

Measuring circuits

System frequency

50 / 60 Hz (settable)

Current transformer

Rated current Inom Option: sensitive ground-fault CT Power consumption

1 or 5 A (settable) IEE < 1.6 A

at Inom = 1 A

Approx. 0.05 VA per phase

at Inom = 5 A

Approx. 0.3 VA per phase

for sensitive ground-fault CT at 1 A Approx. 0.05 VA

Overload capability

Thermal (effective)

500 A for 1 s

150 A for 10 s

20 A continuous

Dynamic (impulse current)

250 x Inom (half cycle)

Overload capability if equipped with

sensitive ground-fault CT

Thermal (effective)

300 A for 1 s

100 A for 10 s

Dynamic (impulse current)

15 A continuous 750 A (half cycle)

Voltage transformer

Type

7SJ621, 7SJ623, 7SJ625 7SJ622, 7SJ624, 7SJ626

Number

Rated voltage Vnom Measuring range

100 V to 225 V 0 V to 170 V

Power consumption at Vnom = 100 V
Overload capability in voltage path (phase-neutral voltage)
Thermal (effective)

< 0.3 VA per phase 230 V continuous

Auxiliary voltage

Rated auxiliary voltage Vaux

DC 24/48 V 60/125 V 110/250 V

115/230 V

Permissible tolerance DC 19-58 V 48150 V 88300 V

92138 V 184265 V

Ripple voltage, peak-to-peak

12 %

Power consumption Quiescent Energized

Approx. 4 W Approx. 7 W

Backup time during loss/short circuit of auxiliary voltage

50 ms at V DC 110 V 20 ms at V DC 24 V 200 ms at 115 V/AC 230 V

Binary inputs/indication inputs

Type

7SJ621, 7SJ623, 7SJ625,

7SJ622, 7SJ624 7SJ626

Number

Voltage range

DC 24250 V

Pickup threshold modifiable by plug-in jumpers

Pickup threshold

DC 19 V

For rated control voltage

24/48/60/ 110/125 V

110/125/ DC 220/250 V

Response time/drop- Approx. 3.5 out time

Power consumption 1.8 mA (independent of operating voltage) energized

Binary outputs/command outputs

Type

7SJ621, 7SJ622 7SJ623, 7SJ624

7SJ625, 7SJ626

Command/indication relay

Contacts per command/ indication relay

1 NO / form A (Two contacts changeable to NC/form

B, via jumpers)

Live status contact

1 NO / NC (jumper) / form A/B

Switching capacity

Make

1000 W / VA

Break

30 W / VA / 40 W resistive /

25 W at L/R 50 ms

DC 250 V

Switching voltage Permissible current

5 A continuous, 30 A for 0.5 s making current,

2000 switching cycles

Electrical tests

Specification

Standards

IEC 60255

ANSI C37.90, C37.90.1, C37.90.2, UL508

Insulation tests

Standards

IEC 60255-5; ANSI/IEEE C37.90.0

Voltage test (100 % test) all circuits except for auxiliary voltage and RS485/RS232 and time synchronization

2.5 kV (r.m.s. value), 50/60 Hz

Auxiliary voltage

DC 3.5 kV

Communication ports and time synchronization

AC 500 V

Impulse voltage test (type test) all circuits, except communication ports and time synchronization, class III

5 kV (peak value); 1.2/50 µs; 0.5 J 3 positive and 3 negative impulses at intervals of 5 s

EMC tests for interference immunity; type tests

Standards

IEC 60255-6; IEC 60255-22 (product standard) EN 50082-2 (generic specification) DIN 57435 Part 303

High-frequency test IEC 60255-22-1, class III and VDE 0435 Part 303, class III

2.5 kV (peak value); 1 MHz; =15 ms; 400 surges per s; test duration 2 s

Electrostatic discharge IEC 60255-22-2 class IV and EN 61000-4-2, class IV
Irradiation with radio-frequency field, non-modulated IEC 60255-22-3 (Report) class III

8 kV contact discharge; 15 kV air gap discharge; both polarities; 150 pF; Ri = 330
10 V/m; 27 to 500 MHz

Irradiation with radio-frequency field, amplitude-modulated IEC 61000-4-3; class III

10 V/m, 80 to 1000 MHz; AM 80 %; 1 kHz

Irradiation with radio-frequency 10 V/m, 900 MHz; repetition

field, pulse-modulated

rate 200 Hz, on duration 50 %

IEC 61000-4-3/ENV 50204; class III

Fast transient interference/burst IEC 60255-22-4 and IEC 61000-44, class IV

4 kV; 5/50 ns; 5 kHz; burst length = 15 ms; repetition rate 300 ms; both polarities; Ri = 50 ; test duration 1 min

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Overcurrent Protection/7SJ62
Technical data

1 2 3 4 5 6 7 8 9 10 11 12 13 14

EMC tests for interference immunity; type tests (cont'd)

High-energy surge voltages (Surge) IEC 61000-4-5; class III Auxiliary voltage

From circuit to circuit: 2 kV; 12 ; 9 µF across contacts: 1 kV; 2 ;18 µF

Binary inputs/outputs

From circuit to circuit: 2 kV; 42 ; 0.5 µF across contacts: 1 kV; 42 ; 0.5 µF

Line-conducted HF, amplitude-modulated IEC 61000-4-6, class III

10 V; 150 kHz to 80 MHz; AM 80 %; 1 kHz

Power frequency magnetic field IEC 61000-4-8, class IV IEC 60255-6

30 A/m; 50 Hz, continuous 300 A/m; 50 Hz, 3 s 0.5 mT, 50 Hz

Oscillatory surge withstand capability ANSI/IEEE C37.90.1
Fast transient surge withstand capability ANSI/IEEE C37.90.1
Radiated electromagnetic interference ANSI/IEEE C37.90.2

2.5 to 3 kV (peak value), 1 to 1.5 MHz damped wave; 50 surges per s; duration 2 s, Ri = 150 to 200
4 to 5 kV; 10/150 ns; 50 surges per s both polarities; duration 2 s, Ri = 80
35 V/m; 25 to 1000 MHz; amplitude and pulse-modulated

Damped wave IEC 60694 / IEC 61000-4-12

2.5 kV (peak value, polarity alternating) 100 kHz, 1 MHz, 10 and 50 MHz, Ri = 200

EMC tests for interference emission; type tests

Standard

EN 50081-* (generic specification)

Conducted interferences

150 kHz to 30 MHz

only auxiliary voltage IEC/CISPR 22 Limit class B

Radio interference field strength 30 to 1000 MHz

IEC/CISPR 11

Limit class B

Units with a detached operator panel must be installed in a metal cubicle to maintain limit class B

Mechanical stress tests

Vibration, shock stress and seismic vibration

During operation

Standards

IEC 60255-21 and IEC 60068-2

Vibration IEC 60255-21-1, class 2 IEC 60068-2-6

Sinusoidal 10 to 60 Hz; ± 0.075 mm amplitude; 60 to 150 Hz; 1 g acceleration frequency sweep 1 octave/min 20 cycles in 3 perpendicular axes

Shock IEC 60255-21-2, class 1 IEC 60068-2-27

Semi-sinusoidal Acceleration 5 g, duration 11 ms; 3 shocks in both directions of 3 axes

Seismic vibration IEC 60255-21-3, class 1 IEC 60068-3-3

During transportation Standards Vibration IEC 60255-21-1, class 2 IEC 60068-2-6
Shock IEC 60255-21-2, Class 1 IEC 60068-2-27 Continuous shock IEC 60255-21-2, class 1 IEC 60068-2-29

IEC 60255-21 and IEC 60068-2
Sinusoidal 5 to 8 Hz: ± 7.5 mm amplitude; 8 to 150 Hz; 2 g acceleration, frequency sweep 1 octave/min 20 cycles in 3 perpendicular axes
Semi-sinusoidal Acceleration 15 g, duration 11 ms 3 shocks in both directions of 3 axes
Semi-sinusoidal Acceleration 10 g, duration 16 ms 1000 shocks in both directions of 3 axes

Climatic stress tests

Temperatures

Type-tested acc. to IEC 60068-2-1 -25 °C to +85 °C /-13 °F to +185 °F and -2, test Bd, for 16 h

Temporarily permissible operating -20 °C to +70 °C /-4 °F to -158 °F temperature, tested for 96 h

Recommended permanent operating temperature acc. to IEC 60255-6 (Legibility of display may be impaired above +55 °C /+131 °F)

-5 °C to +55 °C /+25 °F to +131 °F

L imiting temperature during permanent storage
L imiting temperature during transport

-25 °C to +55 °C /-13 °F to +131 °F -25 °C to +70 °C /-13 °F to +158 °F

Humidity

Permissible humidity

Annual average 75 % relative

It is recommended to arrange the humidity; on 56 days a year up to

units in such a way that they are 95 % relative humidity;

not exposed to direct sunlight or condensation not permissible!

pronounced temperature changes

that could cause condensation.

Unit design

Housing Dimensions

7XP20 See dimension drawings, part 14

Weight Surface-mounting housing Flush-mounting housing
Degree of protection acc. to EN 60529 Surface-mounting housing Flush-mounting housing Operator safety

4.5 kg 4.0 kg
IP 51 Front: IP 51, rear: IP 20; IP 2x with cover

Futher information can be found in the current manual at: www.siemens.com/siprotec

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5/42 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ62
Selection and ordering data

Description 7SJ62 multifunction protection relay
Housing, inputs, outputs Housing 19", 4 line text display, 3 x U, 4 x I, 8 BI, 8 BO, 1 live status-contact Housing 19", 4 line text display, 3 x U, 4 x I, 11 BI,6 BO, 1 live status-contact Housing 19", 4 line text display, 4 x U, 4 x I, 8 BI, 8 BO, 1 live status-contact Housing 19", 4 line text display, 4 x U, 4 x I, 11 BI,6 BO, 1 live status-contact Housing ½19", graphic display, 4 x U, 4 x I,8 BI, 8 BO, 1 live status contact 7) Housing ½19", graphic display, 4 x U, 4 x I, 11 BI, 6 BO, 1 live status contact 7)
Measuring inputs (3 x V/4 x V, 4 x I) Iph = 1 A1), Ie = 1 A1) (min. = 0.05 A) Position 15 only with A, C, E, G Iph = 1 A1), Ie = sensitive (min. = 0.001 A) Position 15 only with B, D, F, H Iph = 5 A1), Ie = 5 A1) (min. = 0.25 A) Position 15 only with A, C, E, G Iph = 5 A1), Ie = sensitive (min. = 0.001 A) Position 15 only with B, D, F, H Iph = 5 A1), Ie = 1 A1) (min. = 0.05 A) Position 15 only with A, C, E,G
Rated auxiliary voltage (power supply, indication voltage) DC 24 to 48 V, threshold binary input DC 19 V 3) DC 60 to 125 V 2), threshold binary input DC 19 V 3) DC 110 to 250 V 2), AC 115 to 230 V4) , threshold binary input DC 88 V 3) DC 110 to 250 V 2), AC 115 to 230 V4) , threshold binary input DC 176 V 3)
Unit version For panel surfacemounting, two-tier terminal top/bottom For panel flushmounting, plug-in terminal (2/3 pin connector) For panel flushmounting, screw-type terminal (direct connection/ring-type cable lugs)

Region-specific default settings/function versions and language settings Region DE, 50 Hz, IEC, language: German, selectable Region World, 50/60 Hz, IEC/ANSI, language: English (GB), selectable Region US, 60 Hz, ANSI, language: English (US), selectable Region FR, 50/60 Hz, IEC/ANSI, language: French, selectable Region World, 50/60 Hz, IEC/ANSI, language: Spanish, selectable Region IT, 50/60 Hz, IEC/ANSI, language: Italian, selectable Region RU, 50/60 Hz, IEC/ANSI, language: Russian, selectable
System interface (Port B): Refer to page 5/114 No system interface Protocols see page 5/114
Service interface (Port C) No interface at rear side DIGSI 4/modem, electrical RS232 DIGSI 4/modem/RTD-box5), electrical RS485 DIGSI 4/modem/RTD-box5)6), optical 820 nm wavelength, ST connector
Measuring/fault recording Fault recording Slave pointer,mean values, min/max values, fault recording

Order No. 7SJ62 - -

See next

page

1
2
5
6
7
2 4 5 6
B D E
A B C D E F G
0

0 1 2 3
1 3

5) T emperature monitoring box 7XV5662- AD10, refer to "Accessories".
6) When using the temperature monitoring box at an optical interface, the additional RS485 fiber-optic converter 7XV5650-0 A00 is required.
7) S tarting from device version .../GG and FW-Version V4.82

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 5/43

Overcurrent Protection/7SJ62
Selection and ordering data

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Description 7SJ62 multifunction protection relay

Order No.

Order code

7SJ62 - -

Designation

ANSI No. Description

Basic version

50/51 50N/51N 50N/51N
50/50N
51 V 49 46
37 47 59N/64 50BF 74TC
86

Control Overcurrent protection I>, I>>, I>>>, Ip Ground-fault protection IE>, IE>>, IE>>>, IEp Insensitive ground-fault protection via IEE function: IEE>, IEE>>, IEEp1) Flexible protection functions (index quantities derived from current): Additional time-overcurrent protection stages I2>, I>>>>, IE>>>> Voltage-dependent inverse-time overcurrent protection Overload protection (with 2 time constants) Phase balance current protection (negative-sequence protection) Undercurrent monitoring Phase sequence Displacement voltage Breaker failure protection Trip circuit supervision 4 setting groups, cold-load pickup Inrush blocking Lockout

V, P, f 27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

IEF V, P, f 27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Intermittent ground fault

Dir

67/67N

Direction determination for overcurrent, phases and ground

Dir

V, P, f 67/67N Direction determination for overcurrent, phases and ground

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Dir IEF

67/67N Direction determination for overcurrent,

phases and ground

Intermittent ground fault

Dir V,P,f IEF 67/67N Direction determination for overcurrent, phases and ground

Intermittent ground fault protection

27/59

Under-/overvoltage

81U/O

Under-/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N)Flexible protection functions (quantities derived from

current & voltages):

32/55/81R Voltage-/power-/p.f.-/rate of freq. change-protection

Intermittent ground-fault

Sens.ground-f.det.

Dir REF

67/67N
67Ns 67Ns 87N

Direction determination for overcurrent, phases and ground Directional sensitive ground-fault detection Directional intermittent ground fault protection 3) High-impedance restricted ground fault

F E
P E F C
F G P C
P G F D 2)

Basic version included
V, P, f = Voltage, power, frequency protection Dir = Directional overcurrent protection IEF = Intermittent ground fault

1) 5 0N/51N only with insensitive ground-current transformer when position 7 = 1, 5, 7.
2) Sensitive ground-current transformer only when position 7 = 2, 6. 3) available beginning with FW / Parameterset-version V4.90

Continued on next page

5/44 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ62
Selection and ordering data

Description 7SJ62 multifunction protection relay

Order No.

Order code

7SJ62 - -

Designation

ANSI No. Description

Basic version

50/51 50N/51N 50N/51N
50/50N
51 V 49 46
37 47 59N/64 50BF 74TC
86

Control Overcurrent protection I>, I>>, I>>>, Ip Ground-fault protection IE>, IE>>, IE>>>, IEp Insensitive ground-fault protection via IEE function: IEE>, IEE>>, IEEp1) Flexible protection functions (index quantities derived from current): Additional time-overcurrent protection stages I2>, I>>>>, IE>>>> Voltage-dependent inverse-time overcurrent protection Overload protection (with 2 time constants) Phase balance current protection (negative-sequence protection) Undercurrent monitoring Phase sequence Displacement voltage Breaker failure protection Trip circuit supervision, 4 setting groups, cold-load pickup Inrush blocking Lockout

Sens.ground-f.det. V,P,f REF
Sens.ground-f.det. Dir IEF REF
Sens.ground-f.det. REF

V, P, f 67Ns Directional sensitive ground-fault detection

67Ns

Directional intermittent ground fault protection 3)

87N

High-impedance restricted ground fault

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

67/67N 67Ns 67Ns 87N

Direction determination for overcurrent, phases and ground Directional sensitive ground-fault detection Directional intermittent ground fault protection 3) High-impedance restricted ground fault Intermittent ground faults

67Ns 67Ns 87N

Directional sensitive ground-fault detection Directional intermittent ground fault protection 3)
High-impedance restricted ground fault

F F 2)
P D 2) F B 2)

Sens.ground-f.det. Motor
V,P,f REF

67Ns

Directional sensitive ground-fault detection

67Ns

Directional intermittent ground fault protection 3)

87N

High-impedance restricted ground fault

48/14

Starting time supervision, locked rotor

66/86

Restart inhibit

51M

Load jam protection, motor statistics

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Sens.ground-f.det. Motor Dir V,P,f REF

67/67N Direction determination for overcurrent, phases and ground

67Ns

Directional sensitive ground-fault detection

67Ns

Directional intermittent ground fault protection 3)

87N

High-impedance restricted ground fault

48/14

Starting time supervision, locked rotor

66/86

Restart inhibit

51M

Load jam protection, motor statistics

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Basic version included
V, P, f = Voltage, power, frequency protection Dir = Directional overcurrent protection IEF = Intermittent ground fault

1) 50N/51N only with insensitive ground-current transformer when position 7 = 1, 5, 7.
2) Sensitive ground-current transformer only when position 7 = 2, 6. 3) available beginning with FW / Parameterset-version V4.90

H F 2)
H H 2) Continued on next page

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 5/45

Overcurrent Protection/7SJ62
Selection and ordering data

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Description 7SJ62 multifunction protection relay

Order No.

Order code

7SJ62 - -

Designation

ANSI No. Description

Basic version

50/51 50N/51N 50N/51N
50/50N
51 V 49 46
37 47 59N/64 50BF 74TC
86

Control Overcurrent protection I>, I>>, I>>>, Ip Ground-fault protection IE>, IE>>, IE>>>, IEp Insensitive ground-fault protection via IEE function: IEE>, IEE>>, IEEp1) Flexible protection functions (index quantities derived from current): Additional time-overcurrent protection, stages I2>, I>>>>, IE>>>> Voltage-dependent inverse-time overcurrent protection Overload protection (with 2 time constants) Phase balance current protection (negative-sequence protection) Undercurrent monitoring Phase sequence Displacement voltage Breaker failure protection Trip circuit supervision 4 setting groups, cold-load pickup Inrush blocking Lockout

Sens.ground-f.det. Motor IEF 67/67N Direction determination for overcurrent, phases and ground

Dir IEF V,P,f REF

67Ns

Directional sensitive ground-fault detection

67Ns

Directional intermittent ground fault protection 4)

87N

High-impedance restricted ground fault

Intermittent ground fault

48/14

Starting time supervision, locked rotor

66/86

Restart inhibit

51M

Load jam protection, motor statistics

27/59

Undervoltage/overvoltage

81O/U

Underfrequency/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Motor V, P, f

67/67N Direction determination for overcurrent,

Dir

phases and ground

48/14

Starting time supervision, locked rotor

66/86

Restart inhibit

51M

Load jam protection, motor statistics

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Motor

48/14 66/86 51M

Starting time supervision, locked rotor Restart inhibit Load jam protection, motor statistics

ARC, fault locator, synchro-check

Without

With auto-reclosure

21FL

With fault locator

79, 21FL With auto-reclosure, with fault locator

With synchro-check3)

25, 79,21FL With synchro-check3), auto-reclosure, fault locator

R H 2)
H G
H A 0 1 2 3 4 7

Basic version included
V, P, f = Voltage, power, frequency protection Dir = Directional overcurrent protection
IEF = Intermittent ground fault
1) 50N/51N only with insensitive ground-current transformer when position 7 = 1, 5, 7.
2) Sensitive ground-current transformer only when position 7 = 2, 6.

3) Synchro-check (no asynchronous switching), one function group; available only with devices 7SJ623, 7SJ624, 7SJ625 and 7SJ626.
4) with FW V4.90

5/46 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ62
Selection and ordering data

Description 7SJ62 multifunction protection relay
System interface (on rear of unit, Port B)
No system interface IEC 60870-5-103 protocol, RS232 IEC 60870-5-103 protocol, RS485 IEC 60870-5-103 protocol, 820 nm fiber, ST connector PROFIBUS DP Slave, RS485 PROFIBUS DP Slave, 820 nm wavelength, double ring, ST connector 1) MODBUS, RS485 MODBUS, 820 nm wavelength, ST connector 2) DNP 3.0, RS485 DNP 3.0, 820 nm wavelength, ST connector 2) IEC 60870-5-103 protocol, redundant, RS485, RJ45 connector 2) IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector (EN 100) IEC 61850, 100 Mbit Ethernet, optical, double, LC connector (EN 100)2) DNP3 TCP + IEC 61850, 100Mbit Eth, electrical, double, RJ45 connector 3) DNP3 TCP + IEC 61850, 100Mbit Eth, optical, double, LC connector 3) PROFINET + IEC 61850, 100Mbit Eth, electrical, double, RJ45 connector 3) PROFINET + IEC 61850, 100Mbit Eth, optical, double, LC connector 3)

Order No.

Order code

7SJ62 - - -

1 2

L 0 A

9 9

L 0 B L 0 D

L 0 E

L 0 G

L 0 H

L 0 P

L 0 R

L 0 S

L 2 R

L 2 S

L 3 R

L 3 S

1) Not with position 9 = "B"; if 9 = "B", please order 7SJ6 unit with RS485 port and separate fiber-optic converters.

For single ring, please order converter 6GK1502-3AB10, not available with position 9 = "B".

For double ring, please order converter 6GK1502-4AB10, not available with position 9 = "B". The converter requires a AC 24 V power supply (e.g. power supply 7XV5810-0BA00).

2) Not available with position 9 = "B".

3) available with V4.9

Sample order Position

I/O's: 11 BI/6 BO, 1 live status contact

Current transformer: 5 A

Power supply: DC 110 to 250 V, AC 115 V to AC 230 V

Unit version: Flush-mounting housing, screw-type terminals

10 Region: US, English language (US); 60 Hz, ANSI

11 Communication: System interface: DNP 3.0, RS485

12 Communication: DIGSI 4, electric RS232

13 Measuring/fault recording: Extended measuring and fault records

14/15 Protection function package: Basic version plus directional TOC

16 With auto-reclosure

Order No. + Order code 7SJ622 5 - 5 E C 9 1 - 3 F A 1 + L 0 G

5 E

L 0 G

1 3

F C

9 10 11 12 13

15
Siemens SIP · Edition No. 8 5/47

Overcurrent Protection/7SJ62
Selection and ordering data

Accessories
1 2 3 4 5 6

Order No.
7XV5662-2AD10 7XV5662-5AD10
C53207-A401-D76-1 C53207-A401-D77-1
7XV5100-4
7XV5103-7AA05 7XV5103-7AA25 7XV5103-7AA50
C53000-G1140-C207-x 1) C53000-G1100-C207-6

Accessories

LSP2289-afp.eps

10 11

Mounting rail

LSP2091-afp.eps

LSP2090-afp.eps

12 13

2-pin connector

3-pin connector

LSP2092-afp.eps

LSP2093-afp.eps

14 15

Short-circuit links

for current terminals for current terminals

5/48 Siemens SIP · Edition No. 8

1) x = please inquire for latest edition (exact Order No.).

Description

Order No.

Size of package

Supplier

Terminal safety cover

Voltage/current terminal 18-pole/12-pole C73334-A1-C31-1

Voltage/current terminal 12-pole/8-pole

C73334-A1-C32-1

Connector 2-pin

C73334-A1-C35-1

Connector 3-pin

C73334-A1-C36-1

Siemens Siemens Siemens Siemens

Crimp connector CI2 0.5 to 1 mm2

0-827039-1

Crimp connector CI2 0.5 to 1 mm2 Crimp connector: Type III+ 0.75 to 1.5 mm2 Crimp connector: Type III+ 0.75 to 1.5 mm2

0-827396-1 0-163084-2 0-163083-7

Crimping tool for Type III+ and matching female
Crimping tool for CI2 and matching female

0-539635-1 0-539668-2 0-734372-1 1-734387-1

4000

taped on reel

4000

taped on reel

Short-circuit links for current terminals for other terminals

C73334-A1-C33-1

C73334-A1-C34-1

Siemens Siemens

Mounting rail for 19" rack

C73165-A63-D200-1 1

Siemens

1) Your local Siemens representative can inform you on local suppliers.

Overcurrent Protection/7SJ62
Connection diagram

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 5/49

Overcurrent Protection/7SJ62
Connection diagram

14 15

5/50 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ62
Connection diagram

7SJ623, 7SJ625

7SJ623x-x B xxx-xxxx

7SJ625x-x B xxx-xxxx

7SJ623x-x D xxx-xxxx

7SJ625x-x D xxx-xxxx

LSA4734a-en.eps

14 15
Siemens SIP · Edition No. 8 5/51

Overcurrent Protection/7SJ62
Connection diagram

7SJ624x-x B xxx-xxxx

7SJ626x-x B xxx-xxxx

7SJ624x-x D xxx-xxxx

7SJ624,

7SJ626

7SJ626x-x D xxx-xxxx

LSA4735a-en.eps

14 15

5/52 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ64
SIPROTEC 7SJ64 multifunction protection relay with synchronization

Function overview

Fig. 5/50 SIPROTEC 7SJ64 multifunction protection relay
Description
The SIPROTEC 7SJ64 can be used as a protective control and monitoring relay for distribution feeders and transmission lines of any voltage in networks that are earthed (grounded), low-resistance grounded, ungrounded, or of a compensated neutral point structure. The relay is suited for networks that are radial or looped, and for lines with single or multi-terminal feeds. The SIPROTEC 7SJ64 is equipped with a synchronization function which provides the operation modes `synchronization check' (classical) and `synchronous/asynchronous switching' (which takes the CB mechanical delay into consideration). Motor protection comprises undercurrent monitoring, starting time supervision, restart inhibit, locked rotor, load jam protection as well as motor statistics.
The 7SJ64 is featuring the "flexible protection functions". Up to 20 protection functions can be added according to individual requirements. Thus, for example, rate-of-frequency-change protection or reverse power protection can be implemented.
The relay provides easy-to-use local control and automation functions. The number of controllable switchgear depends only on the number of available inputs and outputs. The integrated programmable logic (CFC) allows the user to implement their own functions, e.g. for the automation of switchgear (interlocking). CFC capacity is much larger compared to 7SJ63 due to extended CPU power. The user is able to generate user-defined messages as well.
The flexible communication interfaces are open for modern communication architectures with control systems.

LSP2316-afpen.tif

Protection functions · Overcurrent protection · Directional overcurrent protection · Sensitive dir./non-dir. ground-fault detection · Displacement voltage · Intermittent ground-fault protection · Directional intermittent ground fault protection · High-impedance restricted ground fault · Inrush restraint · Motor protection · Overload protection · Temperature monitoring · Under-/overvoltage protection · Under-/overfrequency protection · Rate-of-frequency-change protection · Power protection (e.g. reverse, factor) · Undervoltage-controlled reactive power protection · Breaker failure protection · Negative-sequence protection · Phase-sequence monitoring · Synchronization · Auto-reclosure · Fault locator · Lockout
Control functions/programmable logic · Flexible number of switching devices · Position of switching elements is shown on the graphic
display · Local/remote switching via key-operated switch · Control via keyboard, binary inputs, DIGSI 4 or SCADA system · Extended user-defined logic with CFC (e.g. interlocking)
Monitoring functions · Operational measured values V, I, f, ... · Energy metering values Wp, Wq · Circuit-breaker wear monitoring · Slave pointer · Trip circuit supervision · Fuse failure monitor · 8 oscillographic fault records · Motor statistics
Communication interfaces · System interface
IEC 60870-5-103, IEC 61850 PROFIBUS DP DNP 3 / DNP3 TCP / MODBUS RTU PROFINET · Service interface for DIGSI 4 (modem) · Additional interface for temperature detection (RTD-box) · Front interface for DIGSI 4 · Time synchronization via IRIG B/DCF77

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 5/53

Overcurrent Protection/7SJ64
Application

7 8 9 10 11 12 13 14 15

Fig. 5/51 Function diagram

Application
The SIPROTEC 7SJ64 unit is a numerical protection relay that also performs control and monitoring functions and therefore supports the user in cost-effective power system management, and ensures reliable supply of electric power to the customers. Local operation has been designed according to ergonomic criteria. A large, easyto-read graphic display was a major design aim.
Control
The integrated control function permits control of disconnect devices (electrically operated/motorized switches) or circuitbreakers via the integrated operator panel, binary inputs, DIGSI 4 or the control and protection system (e.g. SICAM). The present status (or position) of the primary equipment can be displayed. 7SJ64 supports substations with single and duplicate busbars. The number of elements that can be controlled (usually 1 to 5) is only restricted by the number of inputs and outputs available. A full range of command processing functions is provided.
Programmable logic
The integrated logic characteristics (CFC) allow users to implement their own functions for automation of switchgear (interlocking) or a substation via a graphic user interface. Due to extended CPU power, the programmable logic capacity is much larger compared to 7SJ63. The user can also generate user-defined messages.
Line protection
The 7SJ64 units can be used for line protection of high and medium-voltage networks with grounded, low-resistance grounded, isolated or compensated neutral point.

Synchronization
In order to connect two components of a power system, the relay provides a synchronization function which verifies that switching ON does not endanger the stability of the power system.
The synchronization function provides the operation modes `synchro-check' (classical) and `synchronous/asynchronous switching' (which takes the c.-b. mechanical delay into consideration).
Motor protection
When protecting motors, the relays are suitable for asynchronous machines of all sizes.
Transformer protection
The 7SJ64 units perform all functions of backup protection supplementary to transformer differential protection. The inrush suppression effectively prevents tripping by inrush currents.
The high-impedance restricted ground-fault protection detects short-circuits and insulation faults of the transformer.
Backup protection
The relays can be used universally for backup protection.
Flexible protection functions
By configuring a connection between a standard protection logic and any measured or derived quantity, the functional scope of the relays can be easily expanded by up to 20 protection stages or protection functions.
Metering values
Extensive measured values, limit values and metered values permit improved system management.

5/54 Siemens SIP · Edition No. 8

ANSI 50, 50N
50, 50N
51, 51V, 51N 67, 67N
67Ns/50Ns 59N/64
67Ns 87N 50BF 79M 25 46 47 49 48 51M 14 66/86 37 38 27, 59 59R 32 27/Q 35 81O/U 81R 21FL

IEC I>, I>>, I>>> IE>, IE>>, IE>>> I>>>>, I2> IE>>>> Ip, IEp Idir>, Idir>>, Ip dir IEdir>, IEdir>>, IEp dir IEE>, IEE>>, IEEp
VE, V0> IIE> IIE dir>
I2> V2>, phase seq. >
I<
V<, V> dV/dt P<>, Q<> Q>/V< cos f>, f< df/dt

Overcurrent Protection/7SJ64
Application

Protection functions Definite-time overcurrent protection (phase/neutral)
Additional definite-time overcurrent protection stages (phase/neutral) via flexible protection functions Inverse overcurrent protection (phase/neutral), phase function with voltage-dependent option Directional overcurrent protection (definite/inverse, phase/neutral), Directional comparison protection Sensitive ground-fault protection Cold load pick-up (dynamic setting change) Displacement voltage, zero-sequence voltage Intermittent ground fault Directional intermittent ground fault protection High-impedance restricted ground-fault protection Breaker failure protection Auto-reclosure Synchronization Phase-balance current protection (negative-sequence protection) Unbalance-voltage protection and/or phase-sequence monitoring Thermal overload protection Starting time supervision Load jam protection Locked rotor protection Restart inhibit Undercurrent monitoring Temperature monitoring via external device (RTD-box), e.g. bearing temperature monitoring Undervoltage/overvoltage protection Rate-of-voltage-change protection Reverse-power, forward-power protection Undervoltage-controlled reactive power protection Power factor protection Overfrequency/underfrequency protection Rate-of-frequency-change protection Fault locator

1 2 3 4 5 6 7 8 9 10 11 12

15
Siemens SIP · Edition No. 8 5/55

LSP2174-afp.tif LSP2299-bfpen.tif

Overcurrent Protection/7SJ64
Construction

Construction

Connection techniques and housing

with many advantages

, ½ and -rack sizes

These are the available housing widths

of the 7SJ64 relays, referred to a

19" module frame system. This means

that previous models can always be

replaced. The height is a uniform 244 mm

for flush-mounting housings and 266 mm

for surface-mounting housings for all

housing widths. All cables can be con-

nected with or without ring lugs. Plug-in terminals are available as an option.

It is thus possible to employ prefabricated

cable harnesses. In the case of surface

Fig. 5/52 Flush-mounting housing

mounting on a panel, the connection terminals are located above and below

with screw-type terminals

in the form of screw-type terminals. The

communication interfaces are located in

a sloped case at the top and bottom of the housing. The housing can also be sup-

plied optionally with a detached operator

panel (refer to Fig. 5/91), or without

operator panel, in order to allow optimum operation for all types of applications.

Fig. 5/53 F ront view of 7SJ64 with × 19" housing

LSP2196-afp.eps

10 11

Fig. 5/54 Housing with plug-in terminals and detached operator panel

LSP2219-afpen.eps LSP2237-afp.tif

14 15
5/56 Siemens SIP · Edition No. 8

Fig. 5/55 Surface-mounting housing with screw-type terminals

Fig. 5/56 Communication interfaces in a sloped case in a surface-mounting housing

Overcurrent Protection/7SJ64
Protection functions

Protection functions

Overcurrent protection (ANSI 50, 50N, 51,51V, 51N)
This function is based on the phaseselective measurement of the three phase currents and the ground current (four transformers). Three definite-time overcurrent protection elements (DMT) exist both for the phases and for the ground. The current threshold and the delay time can be set in a wide range. In addition, inverse-time overcurrent protection characteristics (IDMTL) can be activated. The inverse-time function provides as an option voltage-restraint or voltagecontrolled operating modes. With the "flexible protection functions", further definite-time overcurrent stages can be implemented in the 7SJ64 unit.
Reset characteristics
For easier time coordination with electromechanical relays, reset characteristics according to ANSI C37.112 and IEC 60255-3 / BS 142 standards are applied.
When using the reset characteristic (disk emulation), a reset process is initiated after the fault current has disappeared. This reset process corresponds to the reverse movement of the Ferraris disk of an electromechanical relay (thus: disk emulation).

Fig. 5/57 Definite-time overcurrent protection
Available inverse-time characteristics Characteristics acc. to Inverse Short inverse Long inverse Moderately inverse Very inverse Extremely inverse Definite inverse

Fig. 5/58 Inverse-time overcurrent protection

ANSI/IEEE · · · · · · ·

IEC 60255-3 ·
·
· ·

User-definable characteristics
Instead of the predefined time characteristics according to ANSI, tripping characteristics can be defined by the user for phase and ground units separately. Up to 20 current/time value pairs may be programmed. They are set as pairs of numbers or graphically in DIGSI 4.

Inrush restraint
The relay features second harmonic restraint. If the second harmonic is detected during transformer energization, pickup of non-directional and directional normal elements are blocked.

Cold load pickup/dynamic setting change
For directional and nondirectional overcurrent protection functions the initiation thresholds and tripping times can be switched via binary inputs or by time control.

1 2 3 4 5 6 7 8 9 10 11 12 13

15
Siemens SIP · Edition No. 8 5/57

Overcurrent Protection/7SJ64
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Directional overcurrent protection (ANSI 67, 67N)
Directional phase and ground protection are separate functions. They operate in parallel to the non-directional overcurrent elements. Their pickup values and delay times can be set separately. Definite-time and inverse-time characteristic is offered. The tripping characteristic can be rotated about ± 180 degrees.
By means of voltage memory, directionality can be determined reliably even for close-in (local) faults. If the switching device closes onto a fault and the voltage is too low to determine direction, directionality (directional decision) is made with voltage from the voltage memory. If no voltage exists in the memory, tripping occurs according to the coordination schedule.
For ground protection, users can choose whether the direction is to be determined via zero-sequence system or negativesequence system quantities (selectable). Using negative-sequence variables can be advantageous in cases where the zero voltage tends to be very low due to unfavorable zero-sequence impedances.

Fig. 5/59 Directional characteristic of the directional overcurrent protection

(Sensitive) directional ground-fault detection (ANSI 64, 67Ns/67N)
For isolated-neutral and compensated networks, the direction of power flow in the zero sequence is calculated from the zerosequence current I0 and zero-sequence voltage V0. For networks with an isolated neutral, the reactive current component is evaluated; for compensated networks, the active current component or residual resistive current is evaluated.
For special network conditions, e.g. high-resistance grounded networks with ohmic-capacitive ground-fault current or lowresistance grounded networks with ohmic-inductive current, the tripping characteristics can be rotated approximately ± 45 degrees.
Two modes of ground-fault direction detection can be implemented: tripping or "signalling only mode".
It has the following functions:
· TRIP via the displacement voltage VE. · Two instantaneous elements or one instantaneous plus one
user-defined characteristic.
· Each element can be set in forward, reverse, or nondirectional.
· The function can also be operated in the insensitive mode, as an additional short-circuit protection.
(Sensitive) ground-fault detection (ANSI 50Ns, 51Ns/50N, 51N)
For high-resistance grounded networks, a sensitive input transformer is connected to a phase-balance neutral current transformer (also called core-balance CT).

Fig. 5/60 Directional determination using cosine measurements for compensated networks
The function can also be operated in the insensitive mode, as an additional short-circuit protection.
Intermittent ground-fault protection
Intermittent (re-striking) faults occur due to insulation weaknesses in cables or as a result of water penetrating cable joints. Such faults either simply cease at some stage or develop into lasting short-circuits. During intermittent activity, however, star-point resistors in networks that are impedance-grounded may undergo thermal overloading. The normal ground-fault protection cannot reliably detect and interrupt the current pulses, some of which can be very brief.
The selectivity required with intermittent ground faults is achieved by summating the duration of the individual pulses and by triggering when a (settable) summed time is reached. The response threshold IIE> evaluates the r.m.s. value, referred to one systems period.

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Protection functions

Directional intermittent ground fault protection (ANSI 67Ns)
The directional intermittent ground fault protection has to detect intermittent ground faults in resonant grounded cable systems selectively. Intermittent ground faults in resonant grounded cable systems are usually characterized by the following properties:
· A very short high-current ground current pulse (up to several hundred amperes) with a duration of under 1 ms
· They are self-extinguishing and re-ignite within one halfperiod up to several periods, depending on the power system conditions and the fault characteristic.
· Over longer periods (many seconds to minutes), they can develop into static faults.
Such intermittent ground faults are frequently caused by weak insulation, e.g. due to decreased water resistance of old cables. Ground fault functions based on fundamental component measured values are primarily designed to detect static ground faults and do not always behave correctly in case of intermittent ground faults. The function described here evaluates specifically the ground current pulses and puts them into relation with the zero-sequence voltage to determine the direction.
Phase-balance current protection (ANSI 46) (Negative-sequence protection)
In line protection, the two-element phase-balance current/ negative-sequence protection permits detection on the high side of high-resistance phase-to-phase faults and phase-to-ground faults that are on the low side of a transformer (e.g. with the switch group Dy 5). This provides backup protection for highresistance faults beyond the transformer.
Breaker failure protection (ANSI 50BF)
If a faulted portion of the electrical circuit is not disconnected upon issuance of a trip command, another command can be initiated using the breaker failure protection which operates the circuit-breaker, e.g. of an upstream (higher-level) protection relay. Breaker failure is detected if, after a trip command, current is still flowing in the faulted circuit. As an option, it is possible to make use of the circuit-breaker position indication.
Auto-reclosures (ANSI 79)
Multiple reclosures can be defined by the user and lockout will occur if a fault is present after the last reclosure. The following functions are possible:
· 3-pole ARC for all types of faults
· Separate settings for phase and ground faults
· Multiple ARC, one rapid auto-reclosure (RAR) and up to nine delayed auto-reclosures (DAR)
· Starting of the ARC depends on the trip command selection (e.g. 46, 50, 51, 67)
· Blocking option of the ARC via binary inputs
· ARC can be initiated externally or via CFC
· The directional and non-directional elements can either be blocked or operated non-delayed depending on the autoreclosure cycle
· Dynamic setting change of the directional and non-directional elements can be activated depending on the ready AR
· The AR CLOSE command can be given synchronous by use of the synchronization function.

dv /dt

LSA4113-aen.eps

Fig. 5/61 Flexible protection functions

Flexible protection functions
The 7SJ64 units enable the user to easily add on up to 20 protective functions. To this end, parameter definitions are used to link a standard protection logic with any chosen characteristic quantity (measured or derived quantity) (Fig. 5/98). The standard logic consists of the usual protection elements such as the pickup message, the parameter-definable delay time, the TRIP command, a blocking possibility, etc. The mode of operation for current, voltage, power and power factor quantities can be three-phase or single-phase. Almost all quantities can be operated as greater than or less than stages. All stages operate with protection priority.
Protection stages/functions attainable on the basis of the available characteristic quantities:

Function I>, IE> V<, V>, VE>, dV/dt 3I0>, I1>, I2>, I2/I1, 3V0>, V1><, V2><, Q>< cos (p.f.)>< f><
df/dt><

ANSI No. 50, 50N 27, 59, 59R, 64 50N, 46, 59N, 47 32 55 81O, 81U
81R

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Protection functions

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Synchronization (ANSI 25)
· In case of switching ON the circuit-breaker, the units can check whether the two subnetworks are synchronized (classic synchro-check). Furthermore, the synchronizing function may operate in the "Synchronous/asynchronous switching" mode. The unit then distinguishes between synchronous and asynchronous networks: In synchronous networks, frequency differences between the two subnetworks are almost non-existant. In this case, the circuit-breaker operating time does not need to be considered. Under asynchronous condition, however, this difference is markedly larger and the time window for switching is shorter. In this case, it is recommended to consider the operating time of the circuit- breaker.
The command is automatically pre-dated by the duration of the operating time of the circuit-breaker, thus ensuring that the contacts of the CB close at exactly the right time.
Up to 4 sets of parameters for the synchronizing function can be stored in the unit. This is an important feature when several circuit-breakers with different operating times are to be operated by one single relay.
Thermal overload protection (ANSI 49)
For protecting cables and transformers, an overload protection with an integrated pre-warning element for temperature and current can be applied. The temperature is calculated using a thermal homogeneous-body model (according to IEC 60255-8), which takes account both of the energy entering the equipment and the energy losses. The calculated temperature is constantly adjusted accordingly. Thus, account is taken of the previous load and the load fluctuations.
For thermal protection of motors (especially the stator), a further time constant can be set so that the thermal ratios can be detected correctly while the motor is rotating and when it is stopped. The ambient temperature or the temperature of the coolant can be detected serially via an external temperature monitoring box (resistance-temperature detector box, also called RTD- box). The thermal replica of the overload function is automatically adapted to the ambient conditions. If there is no RTD-box it is assumed that the ambient temperatures are constant.
High-impedance restricted ground-fault protection (ANSI 87N)
The high-impedance measurement principle is an uncomplicated and sensitive method for detecting ground faults, especially on transformers. It can also be applied to motors, generators and reactors when these are operated on an grounded network.
When the high-impedance measurement principle is applied, all current transformers in the protected area are connected in parallel and operated on one common resistor of relatively high R whose voltage is measured (see Fig. 5/99). In the case of 7SJ6 units, the voltage is measured by detecting the current through the (external) resistor R at the sensitive current measurement input IEE.
The varistor V serves to limit the voltage in the event of an internal fault. It cuts off the high momentary voltage spikes occurring at transformer saturation. At the same time, this results in smoothing of the voltage without any noteworthy reduction of the average value. If no faults have occurred and in the event of external faults, the system is at equilibrium, and the voltage through the resistor is approximately zero. In the

Fig. 5/62 High-impedance restricted ground-fault protection
event of internal faults, an imbalance occurs which leads to a voltage and a current flow through the resistor R.
The current transformers must be of the same type and must at least offer a separate core for the high-impedance restricted ground-fault protection. They must in particular have the same transformation ratio and an approximately identical knee-point voltage. They should also demonstrate only minimal measuring errors.
Settable dropout delay times
If the devices are used in parallel with electromechanical relays in networks with intermittent faults, the long dropout times of the electromechanical devices (several hundred milliseconds) can lead to problems in terms of time grading. Clean time grading is only possible if the dropout time is approximately the same. This is why the parameter of dropout times can be defined for certain functions such as time-overcurrent protection, ground short-circuit and phase-balance current protection.
Motor protection
Restart inhibit (ANSI 66/86)
If a motor is started up too many times in succession, the rotor can be subject to thermal overload, especially the upper edges of the bars. The rotor temperature is calculated from the stator current. The reclosing lockout only permits start-up of the motor if the rotor has sufficient thermal reserves for a complete startup (see Fig. 5/100).
Emergency start-up
This function disables the reclosing lockout via a binary input by storing the state of the thermal replica as long as the binary input is active. It is also possible to reset the thermal replica to zero.
Temperature monitoring (ANSI 38)
Up to two temperature monitoring boxes with a total of 12 measuring sensors can be used for temperature monitoring and detection by the protection relay. The thermal status of motors, generators and transformers can be monitored with this device. Additionally, the temperature of the bearings of rotating machines are monitored for limit value violation. The temperatures are being measured with the help of temperature

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Protection functions

detectors at various locations of the device

to be protected. This data is transmitted to the protection relay via one or two

temperature monitoring boxes (see "Acces-

sories", page 5/197).

Starting time supervision (ANSI 48/14)

Starting time supervision protects the

motor against long unwanted start-ups

that might occur in the event of excessive

load torque or excessive voltage drops within the motor, or if the rotor is locked.

Rotor temperature is calculated from

measured stator current. The tripping time

is calculated according to the following equation:

for I > IMOTOR START

I A I

= Actual current flowing

IMOTOR START = Pickup current to detect a

Fig. 5/63

motor start = Tripping time

Motor statistics

Essential information on start-up of the motor (duration, cur-

IA = Rated motor starting current

rent, voltage) and general information on number of starts, total

TA = Tripping time at rated motor starting current (2 times, for operating time, total down time, etc. are saved as statistics in

warm and cold motor)

the device.

The characteristic (equation) can be adapted optimally to the state of the motor by applying different tripping times TA in dependence of either cold or warm motor state. For differentiation of the motor state the thermal model of the rotor is applied.
If the trip time is rated according to the above formula, even a prolonged start-up and reduced voltage (and reduced start-up current) will be evaluated correctly. The tripping time is inverse (current dependent).
A binary signal is set by a speed sensor to detect a blocked rotor. An instantaneous tripping is effected.
Load jam protection (ANSI 51M)
Sudden high loads can cause slowing down and blocking of the motor and mechanical damages. The rise of current due to a load jam is being monitored by this function (alarm and tripping).
The overload protection function is too slow and therefore not suitable under these circumstances.
Phase-balance current protection (ANSI 46) (Negative-sequence protection)
The negative-sequence / phase-balance current protection detects a phase failure or load unbalance due to network asymmetry and protects the rotor from impermissible temperature rise.
Undercurrent monitoring (ANSI 37)
With this function, a sudden drop in current, which can occur due to a reduced motor load, is detected. This may be due to shaft breakage, no-load operation of pumps or fan failure.
1) The 45 to 55, 55 to 65 Hz range is available for fN = 50/60 Hz.

Voltage protection
Overvoltage protection (ANSI 59)
The two-element overvoltage protection detects unwanted network and machine overvoltage conditions. The function can operate either with phase-to-phase, phase-to-ground, positive phase-sequence or negative phase-sequence voltage. Threephase and single-phase connections are possible.
Undervoltage protection (ANSI 27)
The two-element undervoltage protection provides protection against dangerous voltage drops (especially for electric machines). Applications include the isolation of generators or motors from the network to avoid undesired operating states and a possible loss of stability. Proper operating conditions of electrical machines are best evaluated with the positivesequence quantities. The protection function is active over a wide frequency range (45 to 55, 55 to 65 Hz)1). Even when falling below this frequency range the function continues to work, however, with a greater tolerance band.
The function can operate either with phase-to-phase, phaseto-ground or positive phase-sequence voltage, and can be monitored with a current criterion. Three-phase and single-phase connections are possible.
Frequency protection (ANSI 81O/U)
Frequency protection can be used for over-frequency and underfrequency protection. Electric machines and parts of the system are protected from unwanted speed deviations. Unwanted frequency changes in the network can be detected and the load can be removed at a specified frequency setting. Frequency protection can be used over a wide frequency range (40 to 60, 50 to

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Protection functions, functions

70 Hz)1). There are four elements (selectable as overfrequency

or underfrequency) and each element can be delayed separately. Blocking of the frequency protection can be performed if using a

binary input or by using an undervoltage element.

Fault locator (ANSI 21FL)

The integrated fault locator calculates the fault impedance and

the distance-to-fault. The results are displayed in , kilometers

(miles) and in percent of the line length.

3 4 5 6 7 8 9 10 11 12 13 14

Circuit-breaker wear monitoring
Methods for determining circuit-breaker contact wear or the remaining service life of a circuit-breaker (CB) allow CB maintenance intervals to be aligned to their actual degree of wear. The benefit lies in reduced maintenance costs.
There is no mathematically exact method of calculating the wear or the remaining service life of circuit-breakers that takes into account the arc-chamber's physical conditions when the CB opens. This is why various methods of determining CB wear have evolved which reflect the different operator philosophies. To do justice to these, the devices offer several methods:
· I · Ix, with x = 1... 3 · I2t
The devices additionally offer a new method for determining the remaining service life:
· Two-point method
The CB manufacturers double-logarithmic switching cycle diagram (see Fig. 5/101) and the breaking current at the time of contact opening serve as the basis for this method. After CB opening, the two-point method calculates the number of still possible switching cycles. To this end, the two points P1 and P2 only have to be set on the device. These are specified in the CB's technical data. All of these methods are phase-selective and a limit value can be set in order to obtain an alarm if the actual value falls below or exceeds the limit value during determination of the remaining service life.
Commissioning
Commissioning could hardly be easier and is fully supported by DIGSI 4. The status of the binary inputs can be read individually and the state of the binary outputs can be set individually. The operation of switching elements (circuit-breakers, disconnect devices) can be checked using the switching functions of the bay controller. The analog measured values are represented as wideranging operational measured values. To prevent transmission of information to the control center during maintenance, the bay controller communications can be disabled to prevent unnecessary data from being transmitted. During commissioning, all indications with test marking for test purposes can be connected to a control and protection system.
Test operation
During commissioning, all indications can be passed to an automatic control system for test purposes.

Fig. 5/64 CB switching cycle diagram
Functions
Control and automatic functions
Control
In addition to the protection functions, the SIPROTEC 4 units also support all control and monitoring functions that are required for operating medium-voltage or high-voltage substations.
The main application is reliable control of switching and other processes.
The status of primary equipment or auxiliary devices can be obtained from auxiliary contacts and communicated to the 7SJ64 via binary inputs. Therefore it is possible to detect and indicate both the OPEN and CLOSED position or a fault or intermediate circuit-breaker or auxiliary contact position.
The switchgear or circuit-breaker can be controlled via: integrated operator panel binary inputs substation control and protection system DIGSI 4
Automation / user-defined logic
With integrated logic, the user can set, via a graphic interface (CFC), specific functions for the automation of switchgear or substation. Functions are activated via function keys, binary input or via communication interface.
Switching authority
Switching authority is determined according to parameters, communication or by key-operated switch (when available). If a source is set to "LOCAL", only local switching operations are possible. The following sequence of switching authority is laid down: "LOCAL"; DIGSI PC program, "REMOTE".

1) The 40 to 60, 50 to 70 Hz range is available for fN = 50/60 Hz.

Key-operated switch
7SJ64 units are fitted with key-operated switch function for local/remote changeover and changeover between interlocked switching and test operation.

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Functions

Command processing

All the functionality of command processing is offered. This includes the processing of single and double commands with or without feedback, sophisticated monitoring of the control hardware and software, checking of the external process, control actions using functions such as runtime monitoring and automatic command termination after output. Here are some typical applications:
· Single and double commands using 1, 1 plus 1 common or 2 trip contacts
· User-definable bay interlocks
· Operating sequences combining several switching operations such as control of circuit-breakers, disconnectors and grounding switches
· Triggering of switching operations, indications or alarm by combination with existing information
Motor control

Fig. 5/65 Typical wiring for 7SJ642 motor direct control (simplified representation without fuses). Binary output BO6 and BO7 are interlocked so that only one set of contacts are closed at a time.

The SIPROTEC 7SJ64 with high performance relays is well-suited for direct activation of the circuit-breaker, disconnector and grounding switch operating mechanisms in automated substations.

Interlocking of the individual switching devices takes place with the aid of programmable logic. Additional auxiliary relays can be eliminated. This results in less wiring and engineering effort.

Fig. 5/66 Example: Single busbar with circuit-breaker and motor-controlled three-position switch

Indication filtering and delay
Binary indications can be filtered or delayed.
Filtering serves to suppress brief changes in potential at the indication input. The

Fig. 5/67 Example: Circuit-breaker interlocking

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1 2 3 4 5 6 7 8 9 10 11 12 13 14

indication is passed on only if the indication voltage is still present after a set period of time.
In the event of indication delay, there is a wait for a preset time. The information is passed on only if the indication voltage is still present after this time.

Indication derivation
A further indication (or a command) can be derived from an existing indication. Group indications can also be formed. The volume of information to the system interface can thus be reduced and restricted to the most important signals.
Measured values The r.m.s. values are calculated from the acquired current and voltage along with the power factor, frequency, active and reactive power. The following functions are available for measured value processing:
· Currents IL1, IL2, IL3, IE, IEE (67Ns) · Voltages VL1, VL2, VL3, VL1L2, VL2L3, VL3L1, Vsyn · Symmetrical components I1, I2, 3I0; V1, V2, V0 · Power Watts, Vars, VA/P, Q, S (P, Q: total and phase selective) · Power factor (cos ), (total and phase selective) · Frequency
· Energy ± kWh, ± kVarh, forward and reverse power flow
· Mean as well as minimum and maximum current and voltage values
· Operating hours counter
· Mean operating temperature of overload function
· Limit value monitoring Limit values are monitored using programmable logic in the CFC. Commands can be derived from this limit value indication.
· Zero suppression In a certain range of very low measured values, the value is set to zero to suppress interference.

Fig. 5/68 NX PLUS panel (gas-insulated)

Metered values
For internal metering, the unit can calculate an energy metered value from the measured current and voltage values. If an external meter with a metering pulse output is available, the SIPROTEC 4 unit can obtain and process metering pulses via an indication input.
The metered values can be displayed and passed on to a control center as an accumulation with reset. A distinction is made between forward, reverse, active and reactive energy.
Switchgear cubicles for high/medium voltage
All units are designed specifically to meet the requirements of high/medium-voltage applications.
In general, no separate measuring instruments (e.g. for current, voltage, frequency measuring transducer ...) or additional control components are necessary.

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Communication

Communication
In terms of communication, the units offer substantial flexibility in the context of connection to industrial and power automation standards. Communication can be extended or added on thanks to modules for retrofitting on which the common protocols run. Therefore, also in the future it will be possible to optimally integrate units into the changing communication infrastructure, for example in Ethernet networks (which will also be used increasingly in the power supply sector in the years to come).
Serial front interface
There is a serial RS232 interface on the front of all the units. All of the unit's functions can be set on a PC by means of the DIGSI 4 protection operation program. Commissioning tools and fault analysis are also built into the program and are available through this interface.
Rear-mounted interfaces1)
A number of communication modules suitable for various applications can be fitted in the rear of the flush-mounting housing. In the flush-mounting housing, the modules can be easily replaced by the user. The interface modules support the following applications:
· Time synchronization interface All units feature a permanently integrated electrical time synchronization interface. It can be used to feed timing telegrams in IRIG-B or DCF77 format into the units via time synchronization receivers.
· System interface Communication with a central control system takes place through this interface. Radial or ring type station bus topologies can be configured depending on the chosen interface. Furthermore, the units can exchange data through this interface via Ethernet and IEC 61850 protocol and can also be operated by DIGSI.
· Service interface The service interface was conceived for remote access to a number of protection units via DIGSI. It can be an electrical RS232/RS485 interface. For special applications, a maximum of two temperature monitoring boxes (RTD-box) can be connected to this interface as an alternative.
· Additional interface Up to 2 RTD-boxes can be connected via this interface.
System interface protocols (retrofittable)
IEC 61850 protocol
The Ethernet-based IEC 61850 protocol is the worldwide standard for protection and control systems used by power supply corporations. Siemens was the first manufacturer to support this standard. By means of this protocol, information can also be exchanged directly between bay units so as to set up simple masterless systems for bay and system interlocking. Access to the units via the Ethernet bus is also possible with DIGSI. It is also possible to retrieve operating and fault messages and fault recordings via a browser. This Web monitor also provides a few items of unitspecific information in browser windows.

Fig. 5/69 IEC 60870-5-103: Radial fiber-optic connection
Fig. 5/70 Bus structure for station bus with Ethernet and IEC 61850, fiber-optic ring
IEC 60870-5-103 protocol The IEC 60870-5-103 protocol is an international standard for the transmission of protective data and fault recordings. All messages from the unit and also control commands can be transferred by means of published, Siemens-specific extensions to the protocol. Redundant solutions are also possible. Optionally it is possible to read out and alter individual parameters (only possible with the redundant module). PROFIBUS DP protocol PROFIBUS DP is the most widespread protocol in industrial automation. Via PROFIBUS DP, SIPROTEC units make their information available to a SIMATIC controller or, in the control direction, receive commands from a central SIMATIC. Measured values can also be transferred.

1 2 3 4 5 6 7 8 9 10 11 12 13 14

1) F or units in panel surface-mounting housings please refer to note on page 5/193.

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MODBUS RTU protocol
This uncomplicated, serial protocol is mainly used in industry and by power supply corporations, and is supported by a number of unit manufacturers. SIPROTEC units function as MODBUS slaves, making their information available to a master or receiving information from it. A timestamped event list is available.

PROFINET

PROFINET is the ethernet-based successor of PROFIBUS DP and is supported in the variant PROFINET IO. The protocol which is used in industry together with the SIMATIC systems control is realized on the optical and electrical Plus ethernet modules which are delivered since November 2012. All network redundancy procedures which are available for the ethernet modules, such as RSTP, PRP or HSR, are also available for PROFINET. The time synchronization is made via SNTP. The network monitoring is possible via SNMP V2 where special MIB files exist for PROFINET. The LLDP protocol of the device also supports the monitoring of the network topology. Single-point indications, double-point indications, measured and metered values can be transmitted cyclically in the monitoring direction via the protocol and can be selected by the user with DIGSI 4. Important events are also transmitted spontaneously via configurable process alarms. Switching commands can be executed by the system control via the device in the controlling direction. The PROFINET implementation is certified. The device also supports the IEC 61850 protocol as a server on the same ethernet module in addition to the PROFINET protocol. Client server connections are possible for the intercommunication between devices, e.g. for transmitting fault records and GOOSE messages.

Fig. 5/71 System solution/communication
Fig. 5/72 Optical Ethernet communication module for IEC 61850 with integrated Ethernet-switch

LSP3.01-0021.tif

DNP 3.0 protocol
Power utilities use the serial DNP 3.0 (Distributed Network Protocol) for the station and network control levels. SIPROTEC units function as DNP slaves, supplying their information to a master system or receiving information from it.
DNP3 TCP
The ethernet-based TCP variant of the DNP3 protocol is supported with the electrical and optical ethernet module. Two DNP3 TCP clients are supported. Redundant ring structures can be realized for DNP3 TCP with the help of the integrated switch in the module. For instance, a redundant optical ethernet ring can be constructed. Single-point indications, double-point indications, measured and metered values can be confi gured with DIGSI 4 and are transmitted to the DNPi client. Switching commands can be executed in the controlling direction. Fault records of the device are stored in

the binary Comtrade format and can be retrieved via the DNP3 file transfer. The time synchronization is performed via the DNP3 TCP client or SNTP. The device can also be integrated into a network monitoring system via the SNMP V2 protocol. Parallel to the DNP3 TCP protocol the IEC 61850 protocol (the device works as a server) and the GOOSE messages of the IEC 61850 are available for the intercommunication between devices.
System solutions for protection and station control
Together with the SICAM power automation system, SIPROTEC 4 can be used with PROFIBUS DP. Over the low-cost electrical RS485 bus, or interference-free via the optical double ring, the units exchange information with the control system.
Units featuring IEC 60870-5-103 interfaces can be connected to SICAM in parallel via the RS485 bus or radially by fiber-optic link.

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Typical connections

Through this interface, the system is open for the connection of

For IEC 61850, an interoperable system solution is offered with

units of other manufacturers (see Fig. 5/106).
Because of the standardized interfaces, SIPROTEC units can also be integrated into systems of other manufacturers or in SIMATIC. Electrical RS485 or optical interfaces are available. The optimum

SICAM PAS. Via the 100 Mbits/s Ethernet bus, the units are linked with PAS electrically or optically to the station PC. The interface is standardized, thus also enabling direct connection of units of other manufacturers to the Ethernet bus. With IEC 61850, however, the units can also be used in other manufacturers' systems

physical data transfer medium can be chosen thanks to optoelectrical converters. Thus, the RS485 bus allows low-cost wiring

(see Fig. 5/107).

in the cubicles and an interference-free optical connection to the

master can be established.

Typical connections

Connection of current and voltage transformers

Standard connection

For grounded networks, the ground current is obtained from the phase currents by the residual current circuit.

Fig. 5/73 Residual current circuit without directional element

Fig. 5/74 Sensitive ground current detection without directional element

Fig. 5/75 Residual current circuit with directional element

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Typical connections

Connection for compensated networks

The figure shows the connection of two phase-to-ground voltages and the VE

voltage of the open delta winding and a

phase-ground neutral current transformer

for the ground current. This connection maintains maximum precision for direc-

tional ground-fault detection and must be

used in compensated networks.

Fig. 5/113 shows sensitive directional

ground-fault detection.

Fig. 5/76 Sensitive directional ground-fault detection with directional element for phases

Connection for isolated-neutral

or compensated networks only

If directional ground-fault protection is not used, the connection can be made

with only two phase current transformers. Directional phase short-circuit protection

can be achieved by using only two

primary transformers.

Fig. 5/77 Isolated-neutral or compensated networks

11 12

Connection for the synchronization function
The 3-phase system is connected as reference voltage, i. e. the outgoing voltages as well as a single-phase voltage, in this case a busbar voltage, that has to be synchronized.

Fig. 5/78 Measuring of the busbar voltage and the outgoing feeder voltage for synchronization

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Typical applications

Overview of connection types

Type of network

Function

Current connection

Voltage connection

(Low-resistance) grounded network Overcurrent protection

Residual circuit, with 3 phase-current

phase/ground non-directional transformers required, phase-balance

neutral current transformer possible

(Low-resistance) grounded networks Sensitive ground-fault protection Phase-balance neutral current

transformers required

Isolated or compensated networks Overcurrent protection phases Residual circuit, with 3 or 2 phase

non-directional

current transformers possible

(Low-resistance) grounded networks Overcurrent protection

Residual circuit, with 3 phase-current Phase-to-ground connection or

phases directional

transformers possible

phase-to-phase connection

Isolated or compensated networks Overcurrent protection phases directional
(Low-resistance) grounded networks Overcurrent protection ground directional

Isolated networks

Sensitive ground-fault protection

Residual circuit, with 3 or 2 phase-

Phase-to-ground connection or

current transformers possible

phase-to-phase connection

Residual circuit, with 3 phase-current Phase-to-ground connection required

transformers required, phase-balance

neutral current transformers possible

Residual circuit, if ground current

3 times phase-to-ground connection or

> 0.05 IN on secondary side, otherwise phase-to-ground connection with open

phase-balance neutral current

delta winding

transformers required

Compensated networks

Sensitive ground-fault protection Phase-balance neutral current

cos measurement

transformers required

Phase-to-ground connection with open delta winding required

Typical applications

Application examples

Synchronization function

When two subnetworks must be interconnected, the synchronization function monitors whether the subnetworks are synchronous and can be connected without risk of losing stability.

As shown in Fig. 5/116, load is being fed from a generator to a busbar via a transformer. It is assumed that the frequency difference of the 2 subnetworks is such that the device determines asynchronous system conditions.

1) Synchronization function 2) Auto-reclosure function

The voltages of the busbar and the feeder

should be the same when the contacts are made; to ensure this condition the

Fig. 5/79 Measuring of busbar and feeder voltages for synchronization

synchronism function must run in the

"synchronous/asynchronous switching" mode. In this mode, the operating time of the CB can be set within the relay. Differences between angle and frequency can then be calculated by the relay while taking into account the operating time of the

The vector group of the transformer can be considered by setting parameters. Thus no external circuits for vector group adaptation are required.

CB. From these differences, the unit derives the exact time for

This synchronism function can be applied in conjunction with the

issuing the CLOSE command under asynchronous conditions.

auto-reclosure function as well as with the control function CLOSE

When the contacts close, the voltages will be in phase.

commands (local/remote).

7 8 9 10 11 12 13 14

15
Siemens SIP · Edition No. 8 5/69

Overcurrent Protection/7SJ64
Typical applications

Connection of circuit-breaker

Undervoltage releases

Undervoltage releases are used for auto-

matic tripping of high-voltage motors.

Example: DC supply voltage of control system fails

and manual electric tripping is no longer

possible.

Automatic tripping takes place when voltage across the coil drops below the

trip limit. In Figure 5/172, tripping occurs

due to failure of DC supply voltage, by

automatic opening of the live status contact upon failure of the protection unit

or by short-circuiting the trip coil in event

of a network fault.

Fig. 5/80 Undervoltage release with make contact 50, 51

In Fig. 5/118 tripping is by failure of auxil-

iary voltage and by interruption of tripping circuit in the event of network failure. Upon

failure of the protection unit, the tripping

circuit is also interrupted, since contact

held by internal logic drops back into open

position.

Fig. 5/81 Undervoltage release with locking contact (trip signal 50 is inverted)

15
5/70 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ64
Typical applications

Trip circuit supervision (ANSI 74TC)

One or two binary inputs can be used for monitoring the circuit-breaker trip coil

including its incoming cables. An alarm

signal occurs whenever the circuit is

interrupted.

Lockout (ANSI 86)

All binary outputs can be stored like LEDs

and reset using the LED reset key. The lockout state is also stored in the event of

supply voltage failure. Reclosure can only

occur after the lockout state is reset.

Reverse-power protection for dual supply (ANSI 32R)

If power is fed to a busbar through two

parallel infeeds, then in the event of any

fault on one of the infeeds it should be

Fig. 5/82 Trip circuit supervision with 2 binary inputs

selectively interrupted. This ensures a

continued supply to the busbar through

the remaining infeed. For this purpose,

directional devices are needed which detect a short-circuit current or a power

flow from the busbar in the direction of

the infeed. The directional overcurrent

protection is usually set via the load current. It cannot be used to deactivate

low-current faults. Reverse-power protec-

tion can be set far below the rated power.

This ensures that it also detects power feedback into the line in the event of low-

current faults with levels far below the

load current. Reverse-power protection

is performed via the "flexible protection

functions" of the 7SJ64.

Fig. 5/83 Reverse-power protection for dual supply

15
Siemens SIP · Edition No. 8 5/71

Overcurrent Protection/7SJ64
Technical data

1 2 3 4 5 6 7 8 9 10 11 12

General unit data

Measuring circuits

System frequency

50 / 60 Hz (settable)

Current transformer

Rated current Inom

1 or 5 A (settable)

Option: sensitive ground-fault CT IEE < 1.6 A

Power consumption

at Inom = 1 A

Approx. 0.05 VA per phase

at Inom = 5 A

Approx. 0.3 VA per phase

for sensitive ground-fault CT at 1 A Approx. 0.05 VA

Overload capability Thermal (effective)
Dynamic (impulse current)

500 A for 1 s 150 A for 10 s 20 A continuous 250 x Inom (half cycle)

Overload capability if equipped with

sensitive ground-fault CT

Thermal (effective)

300 A for 1 s

100 A for 10 s

15 A continuous

Dynamic (impulse current)

750 A (half cycle)

Voltage transformer

Rated voltage Vnom Measuring range

100 V to 225 V 0 V to 200 V

Power consumption at Vnom = 100 V
Overload capability in voltage path (phase-neutral voltage)
Thermal (effective)

< 0.3 VA per phase 230 V continuous

Auxiliary voltage (via integrated converter)

Rated auxiliary voltage Vaux DC

Permissible tolerance

24/48 V 60/125 V 110/250 V 1958 V 48150 V 88300 V

Ripple voltage, peak-to-peak

12 % of rated auxiliary voltage

Power consumption

7SJ640 7SJ641 7SJ645 7SJ647 7SJ642

Quiescent Energized

Approx. 5 W Approx. 9 W

5.5 W 6.5 W 7.5 W 12.5 W 15 W 21 W

Backup time during loss/short-circuit of auxiliary direct voltage

50 ms at V > DC 110 V 20 ms at V > DC 24 V

Rated auxiliary voltage Vaux AC

Permissible tolerance

115 V/230 V 92 32 V/184265 V

Power consumption

7SJ640 7SJ641 7SJ645 7SJ647 7SJ642

Quiescent Energized

Approx. 7 W 9 W 12 W 16 W Approx. 12 W 19 W 23 W 33 W

Backup time during loss/short-circuit of auxiliary alternating voltage

200 ms

Binary outputs/command outputs

Type

7SJ640 7SJ641 7SJ642 7SJ645 7SJ647

Number (marshallable) 7

Voltage range

DC 24 250 V

Pickup threshold modifiable by plug-in jumpers

Pickup threshold DC DC 19 V

DC 88 V

For rated control voltage

DC 24/48/60/110/ DC 110/125/220/250 V

125 V

Power consumption energized

0.9 mA (independent of operating voltage) for BI 8...19 / 21...32; 1.8 mA for BI 1...7 / 20/33...48

Binary outputs/command outputs

Type

7SJ640 7SJ641 7SJ642 7SJ645 7SJ647

Command/indication 5 relay

Contacts per command/ 1 NO / form A indication relay

Live status contact

1 NO / NC (jumper) / form A / B

Switching capacity Make 1000 W / VA

Break 30 W / VA / 40 W resistive / 25 W at L/R 50 ms

Switching voltage

DC 250 V

Permissible current

5 A continuous, 30 A for 0.5 s making current, 2000 switching cycles

Power relay (for motor control)

Type

7SJ640 7SJ642 7SJ645 7SJ647 7SJ641

Number

2 (4) 4 (8) 4 (8)

Number of contacts/relay

2 NO / form A

Switching capacity Make 1000 W / VA at 48 V ... 250 V / 500 W at 24 V

Break 1000 W / VA at 48 V ... 250 V / 500 W at 24 V

Switching voltage

DC 250 V

Permissible current

5 A continuous, 30 A for 0.5 s

15
5/72 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ64
Technical data

Electrical tests

Specification

Standards

IEC 60255 ANSI C37.90, C37.90.1, C37.90.2, UL508

Insulation tests

Standards

IEC 60255-5; ANSI/IEEE C37.90.0

Voltage test (100 % test) all circuits except for auxiliary voltage and RS485/RS232 and time synchronization

2.5 kV (r.m.s. value), 50/60 Hz

Auxiliary voltage

DC 3.5 kV

Communication ports and time synchronization

AC 500 V

EMC tests for interference immunity; type tests

Standards

IEC 60255-6; IEC 60255-22 (product standard) EN 50082-2 (generic specification) DIN 57435 Part 303

High-frequency test IEC 60255-22-1, class III and VDE 0435 Part 303, class III

2.5 kV (peak value); 1 MHz; =15 ms; 400 surges per s; test duration 2 s

Electrostatic discharge IEC 60255-22-2 class IV and EN 61000-4-2, class IV
Irradiation with radio-frequency field, non-modulated IEC 60255-22-3 (Report) class III

8 kV contact discharge; 15 kV air gap discharge; both polarities; 150 pF; Ri = 330
10 V/m; 27 to 500 MHz

Irradiation with radio-frequency field, amplitude-modulated IEC 61000-4-3; class III

10 V/m, 80 to 1000 MHz; AM 80 %; 1 kHz

Irradiation with radio-frequency 10 V/m, 900 MHz; repetition

field, pulse-modulated

rate 200 Hz, on duration 50 %

IEC 61000-4-3/ENV 50204; class III

Fast transient interference/burst 4 kV; 5/50 ns; 5 kHz;

IEC 60255-22-4 and IEC 61000-4- burst length = 15 ms;

4, class IV

repetition rate 300 ms; both polarities;

Ri = 50 ; test duration 1 min

High-energy surge voltages

(Surge)

IEC 61000-4-5; class III

Auxiliary voltage

From circuit to circuit: 2 kV; 12 ; 9 µF

across contacts: 1 kV; 2 ;18 µF

Binary inputs/outputs

From circuit to circuit: 2 kV; 42 ; 0.5 µF across contacts: 1 kV; 42 ; 0.5 µF

Line-conducted HF, amplitude-modulated IEC 61000-4-6, class III

10 V; 150 kHz to 80 MHz; AM 80 %; 1 kHz

Power frequency magnetic field IEC 61000-4-8, class IV IEC 60255-6

30 A/m; 50 Hz, continuous 300 A/m; 50 Hz, 3 s 0.5 mT, 50 Hz

Oscillatory surge withstand capability ANSI/IEEE C37.90.1
Fast transient surge withstand capability ANSI/IEEE C37.90.1

2.5 to 3 kV (peak value), 1 to 1.5 MHz damped wave; 50 surges per s; duration 2 s, Ri = 150 to 200
4 to 5 kV; 10/150 ns; 50 surges per s both polarities; duration 2 s, Ri = 80

Radiated electromagnetic interference ANSI/IEEE C37.90.2

35 V/m; 25 to 1000 MHz; amplitude and pulse-modulated

Damped wave IEC 60694 / IEC 61000-4-12

2.5 kV (peak value, polarity alternating) 100 kHz, 1 MHz, 10 and 50 MHz, Ri = 200

EMC tests for interference emission; type tests

Standard

EN 50081-* (generic specification)

Conducted interferences

150 kHz to 30 MHz

only auxiliary voltage IEC/CISPR 22 Limit class B

Radio interference field strength 30 to 1000 MHz

IEC/CISPR 11

Limit class B

Units with a detached operator panel must be installed in a metal cubicle to maintain limit class B

Mechanical stress tests

Vibration, shock stress and seismic vibration

During operation

Standards

IEC 60255-21 and IEC 60068-2

Vibration IEC 60255-21-1, class 2 IEC 60068-2-6

Sinusoidal 10 to 60 Hz; ± 0.075 mm amplitude; 60 to 150 Hz; 1 g acceleration frequency sweep 1 octave/min 20 cycles in 3 perpendicular axes

Shock IEC 60255-21-2, class 1 IEC 60068-2-27

Semi-sinusoidal Acceleration 5 g, duration 11 ms; 3 shocks in both directions of 3 axes

Seismic vibration IEC 60255-21-3, class 1 IEC 60068-3-3

During transportation

Standards

IEC 60255-21 and IEC 60068-2

Vibration IEC 60255-21-1, class 2 IEC 60068-2-6

Sinusoidal 5 to 8 Hz: ± 7.5 mm amplitude; 8 to 150 Hz; 2 g acceleration, frequency sweep 1 octave/min 20 cycles in 3 perpendicular axes

Shock IEC 60255-21-2, Class 1 IEC 60068-2-27

Semi-sinusoidal Acceleration 15 g, duration 11 ms 3 shocks in both directions of 3 axes

Continuous shock IEC 60255-21-2, class 1 IEC 60068-2-29

Semi-sinusoidal Acceleration 10 g, duration 16 ms 1000 shocks in both directions of 3 axes

1 2 3 4 5 6 7 8 9 10 11 12 13 14

15
Siemens SIP · Edition No. 8 5/73

Overcurrent Protection/7SJ64
Technical data

Climatic stress tests

Temperatures Type-tested acc. to IEC 60068-2-1 -25 °C to +85 °C /-13 °F to +185 °F

and -2, test Bd, for 16 h

Temporarily permissible operating -20 °C to +70 °C /-4 °F to +158 °F

temperature, tested for 96 h Recommended permanent

-5 °C to +55 °C /+25 °F to +131 °F

operating temperature acc. to

IEC 60255-6

(Legibility of display may be

impaired above +55 °C /+131 °F) Limiting temperature during -25 °C to +55 °C /-13 °F to +131 °F

permanent storage

Limiting temperature during -25 °C to +70 °C /-13 °F to +158 °F

transport

Humidity

Permissible humidity

Annual average 75 % relative humi-

It is recommended to arrange the dity; on 56 days a year up to 95 %

units in such a way that they are relative humidity; condensation not

not exposed to direct sunlight or permissible! pronounced temperature changes

that could cause condensation.

Unit design

Type
6 Housing

7SJ640 7SJ642
7XP20

7SJ641

7SJ645 7SJ647

Dimensions

See dimension drawings, part 14 of

this catalog

Weight in kg

Housing width

Housing width ½

Housing width

Surface-mounting housing

Flush-mounting housing

Housing for detached operator

operator panel Detached operator panel

2.5

Degree of protection

acc. to EN 60529

Surface-mounting housing Flush-mounting housing

Operator safety

IP 51 Front: IP 51, rear: IP 20; IP 2x with cover

Futher information can be found in the current manual at: www.siemens.com/siprotec

15
5/74 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ64
Selection and ordering data

Description
7SJ64 multifunction protection relay with synchronization
Housing, binary inputs and outputs Housing 19", 7 BI, 5 BO, 1 live status contact, text display 4 x 20 character (only for 7SJ640) 9th position only with: B, D, E Housing ½ 19", 15 BI, 13 BO (1 NO/NC or 1a/b contact), 1 live status contact, graphic display Housing ½ 19", 20 BI, 8 BO, 2 power relays (4 contacts), 1 live status contact, graphic display Housing 19", 33 BI, 11 BO, 4 power relays (8 contacts), 1 live status contact, graphic display Housing 19", 48 BI, 21 BO, 4 power relays (8 contacts), 1 live status contact, graphic display
Measuring inputs (4 x V, 4 x I) Iph = 1 A1), Ie = 1 A1) (min. = 0.05 A) Position 15 only with A, C, E, G Iph = 1 A1), Ie = sensitive (min. = 0.001 A) Position 15 only with B, D, F, H Iph = 5 A1), Ie = 5 A1) (min. = 0.25 A) Position 15 only with A, C, E, G Iph = 5 A1), Ie = sensitive (min. = 0.001 A) Position 15 only with B, D, F, H Iph = 5 A1), Ie = 1 A1) (min. = 0.05 A) Position 15 only with A, C, E,G
Rated auxiliary voltage (power supply, binary inputs) DC 24 to 48 V, threshold binary input DC 19 V 3) DC 60 to 125 V 2), threshold binary input DC19 V 3) DC 110 to 250 V 2), AC 115 to 230 V, threshold binary input DC 88 V 3)
Unit version Surface-mounting housing, plug-in terminals, detached operator panel, panel mounting in low-voltage housing Surface-mounting housing, 2-tier terminals on top/bottom Surface-mounting housing, screw-type terminals (direct connection/ring-type cable lugs), detached operator panel, panel mounting in low-voltage housing Flush-mounting housing, plug-in terminals (2/3 pin connector) Flush-mounting housing, screw-type terminals (direct connection/ring-type cable lugs) Surface-mounting housing, screw-type terminals (direct connection/ring-type cable lugs), without operator panel, panel mounting in low-voltage housingg Surface-mounting housing, plug-in terminals, without operator panel, panel mounting in low-voltage housing
Region-specific default settings/function versions and language settings Region DE, 50 Hz, IEC, language: German (language selectable) Region World, 50/60 Hz, IEC/ANSI, language: English (GB) (language selectable) Region US, 60 Hz, ANSI, language: English (US) (language selectable) Region FR, 50/60 Hz, IEC/ANSI, language: French (language selectable) Region World, 50/60 Hz, IEC/ANSI, language: Spanish (language selectable) Region IT, 50/60 Hz, IEC/ANSI, language: Italian (language selectable) Region RU, 50/60 Hz, IEC/ANSI, language: Russian(language can be changed)

Order No. 7SJ64 - -
0 1
See next page 2 5 7
1 2 5 6
7
2 4 5
A B
C D E F G
A B C D E F G

1 2 3 4 5 6 7 8 9 10 11 12

14 15
Siemens SIP · Edition No. 8 5/75

Overcurrent Protection/7SJ64
Selection and ordering data

1 2 3 4 5 6 7 8 9 10 11

Description 7SJ64 multifunction protection relay with synchronization
System interface (on rear of unit, Port B) No system interface IEC 60870-5-103 protocol, RS232 IEC 60870-5-103 protocol, RS485 IEC 60870-5-103 protocol, 820 nm fiber, ST connector PROFIBUS DP Slave, RS485 PROFIBUS DP Slave, 820 nm wavelength, double ring, ST connector 1) MODBUS, RS485 MODBUS, 820 nm wavelength, ST connector 2) DNP 3.0, RS485 DNP 3.0, 820 nm wavelength, ST connector 2) IEC 60870-5-103 protocol, redundant, RS485, RJ45 connector 2) IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector (EN 100) IEC 61850, 100 Mbit Ethernet, optical, double, LC connector (EN 100) 2) DNP3 TCP + IEC 61850, 100Mbit Eth, electrical, double, RJ45 connector 4) DNP3 TCP + IEC 61850, 100Mbit Eth, optical, double, LC connector 4) PROFINET + IEC 61850, 100Mbit Eth, electrical, double, RJ45 connector 4) PROFINET + IEC 61850, 100Mbit Eth, optical, double, LC connector 4) Only Port C (service interface) DIGSI 4/modem, electrical RS232 DIGSI 4/modem/RTD-box3), electrical RS485 Port C and D (service and additional interface) Port C (service interface) DIGSI 4/modem, electrical RS232 DIGSI 4/modem/RTD-box3), electrical RS485 PortD(additional interface) RTD-box3), 820 nm fiber, ST connector 5) RTD-box3), electrical RS485 Measuring/fault recording Fault recording Slave pointer,mean values, min/max values, fault recording

Order No.

Order code

7SJ64 - - -

See

following

pages

L 0A

L 0B

L 0D

L 0E

L 0G

L 0H

L 0P

L 0R

L 0S

L 2R

L 2S

L 3R

L 3S

1 2
A F
1 3

12 13 14

1) Not with position 9 = "B"; if 9 = "B", please order 7SJ6 unit with RS485 port and separate fiber-optic converters. For single ring, please order converter 6GK1502-2CB10, not available with position 9 = "B". For double ring, please order converter 6GK1502-3CB10, not available with position 9 = "B". The converter requires a AC 24 V power supply (e.g. power supply 7XV5810-0BA00).

2) Not available with position 9 = "B".
3) Temperature monitoring box 7XV5662- AD10, refer to "Accessories".
4) Available with V4.9
5) When using the temperature monitoring box at an optical interface, the additional RS485 fiber-optic converter 7XV5650-0 A00 is required.

15
5/76 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ64
Selection and ordering data

Description 7SJ64 multifunction protection relay with synchronization

Order No.

Order code

7SJ64 - - -

Designation

ANSI No. Description

Basic version

50/51 50N/51N 50N/51N
50/50N
51 V 49 46
37 47 59N/64 50BF 74TC
86

Control Overcurrent protection I>, I>>, I>>>, Ip Ground-fault protection IE>, IE>>, IE>>>, IEp Insensitive ground-fault protection through IEE function: IEE>, IEE>>, IEEp1) Flexible protection functions (index quantities derived from current): Additional time-overcurrent protection stages I2>, I>>>>, IE>>>> Voltage-dependent inverse-time overcurrent protection Overload protection (with 2 time constants) Phase balance current protection (negative-sequence protection) Undercurrent monitoring Phase sequence Displacement voltage Breaker failure protection Trip circuit supervision 4 setting groups, cold-load pickup, Inrush blocking Lockout

V, P, f 27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

IEF V, P, f 27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R currentandvoltages):Voltage,power,p.f.,rate-of-frequency-

change protection Intermittent ground fault

Dir

67/67N

Direction determination for overcurrent, phases and ground

Dir

V, P, f 67/67N Direction determination for overcurrent, phases and ground

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Dir V,P,f IEF 67/67N Direction determination for overcurrent, phases and ground

Intermittent ground fault protection

27/59

Under-/overvoltage

81U/O

Under-/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N)Flexible protection functions (quantities derived from

current & voltages)

32/55/81R Voltage-/power-/p.f.-/rate of freq. change-protection

Intermittent ground-fault

Dir IEF

67/67N Direction determination for overcurrent, phases and ground

Intermittent ground fault

Sens.ground-f.det. Motor Dir V,P,f REF

67/67N 67Ns
67Ns 87N

Direction determination for overcurrent, phases and ground Directional sensitive ground-fault detection Directional intermittent ground fault protection 3) High-impedance restricted ground fault

F A F E P E F C
F G
P G P C F D 2)

1 2 3 4 5 6 7 8 9 10 11 12 13

Basic version included
V, P, f = Voltage, power, frequency protection Dir = Directional overcurrent protection IEF = Intermittent ground fault

1) O nly with insensitive ground-current transformer when position 7 = 1, 5, 7.
2) F or isolated/compensated networks only with sensitive ground-current transformer when position 7 = 2, 6.
3) available with V4.9

Continued on next page

14 15

Siemens SIP · Edition No. 8 5/77

Overcurrent Protection/7SJ64
Selection and ordering data

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Description 7SJ64 multifunction protection relay with synchronization

Order No.

Order code

7SJ64 - - -

Designation

ANSI No. Description

Basic version

50/51 50N/51N 50N/51N
50/50N
51 V 49 46
37 47 59N/64 50BF 74TC
86

Control Overcurrent protection I>, I>>, I>>>, Ip Ground-fault protection IE>, IE>>, IE>>>, IEp Insensitive ground-fault protection via IEE function: IEE>, IEE>>, IEEp1) Flexible protection functions (index quantities derived from current): Additional time-overcurrent protection stages I2>, I>>>>, IE>>>> Voltage-dependent inverse-time overcurrent protection Overload protection (with 2 time constants) Phase balance current protection (negative-sequence protection) Undercurrent monitoring Phase sequence Displacement volt Breaker failure protection Trip circuit supervision 4 setting groups, cold-load pickup Inrush blocking Lockout

Sens.ground-f.det. Motor Dir V,P,f REF

67Ns 67Ns

Directional sensitive ground-fault detection Directional intermittent ground fault protection 3)

87N

High-impedance restricted ground fault

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Sens.ground-f.det. Motor IEF 67/67N

Dir V,P,f REF

67Ns

87N

Directional sensitive ground-fault detection, phases and ground Directional sensitive ground-fault detection Directional intermittent ground fault protection 3)
High-impedance restricted ground fault Intermittent ground fault

Sens.ground-f.det. Motor Dir V,P,f REF

67Ns 67Ns
87N

Directional sensitive ground-fault detection Directional intermittent ground fault protection 3)
High-impedance restricted ground fault

Sens.ground-f.det. Motor Dir V,P,f REF
Sens.ground-f.det. Motor Dir V,P,f REF

67Ns

Directional sensitive ground-fault detection

67Ns

Directional intermittent ground fault protection 3)

87N

High-impedance restricted ground fault

48/14

Starting time supervision, locked rotor

66/86

Restart inhibit

51M

Load jam protection, motor statistics

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

67/67N Direction determination for overcurrent, phases and ground

67Ns

Directional sensitive ground-fault detection

67Ns

Directional intermittent ground fault protection 3)

87N

High-impedance restricted ground fault

48/14

Starting time supervision, locked rotor

66/86

Restart inhibit

51M

Load jam protection, motor statistics

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Basic version included

1) Only with insensitive ground-current transformer when position 7 = 1, 5, 7.

V, P, f = Voltage, power, frequency protection 2) For isolated/compensated networks only with sensitive ground-current

Dir = Directional overcurrent protection

transformer when position 7 = 2, 6.

IEF = Intermittent ground fault

3) available with V4.9

F F 2) P D 2) F B 2)
H F 2)
H H 2) Continued on next page

5/78 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ64
Selection and ordering data

Description 7SJ64 multifunction protection relay with synchronization

Order No.

Order code

7SJ64 - - -

Designation

ANSI No. Description

Basic version

50/51 50N/51N 50N/51N
50/50N
51 V 49 46
37 47 59N/64 50BF 74TC
86

Sens.ground-f.det. Motor
Dir V,P,f REF

67/67N Direction determination for overcurrent, phases and ground

67Ns

Directional sensitive ground-fault detection

67Ns

Directional intermittent ground fault protection 3)

87N

High-impedance restricted ground fault

Intermittent ground fault

48/14

Starting time supervision, locked rotor

66/86

Restart inhibit

51M

Load jam protection, motor statistics

27/59

Undervoltage/overvoltage

81O/U

Underfrequency/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Motor V, P, f 67/67N Direction determination for overcurrent,

Dir

phases and ground

48/14

Starting time supervision, locked rotor

66/86

Restart inhibit

51M

Load jam protection, motor statistics

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27/Q

Undervoltage-controlled reactive power protection 3)

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Motor

48/14 66/86 51M

Starting time supervision, locked rotor Restart inhibit Load jam protection, motor statistics

ARC, fault locator, synchronization

Without

With auto-reclosure

21FL

With fault locator

79, 21FL With auto-reclosure, with fault locator

With synchronization

25, 79,21FL With synchronization, auto-reclosure, fault locator

ATEX100 Certification For protection of explosion-protected motors (increased-safety type of protection "e")

R H 2)
H G
H A 0 1 2 3 4 7 Z X 9 9 2)

1 2 3 4 5 6 7 8 9 10 11 12 13

Basic version included
V, P, f = Voltage, power, frequency protection Dir = Directional overcurrent protection

1) Only with insensitive ground-current transformer when position 7 = 1, 5, 7. 2) This variantmight be supplied with a previous firmware version. 3) available with V4.9

Siemens SIP · Edition No. 8 5/79

Overcurrent Protection/7SJ64
Selection and ordering data

Accessories
1 2 3 4 5 6

Description
Temperature monitoring box AC/DC 24 to 60 V AC/DC 90 to 240 V
Varistor/VoltageArrester Voltage arrester for high-impedance REF protection 125 Vrms; 600 A; 1S/S 256 240 Vrms; 600 A; 1S/S 1088
Connecting cable Cable between PC/notebook (9-pin con.) and protection unit (9-pin connector) (contained in DIGSI 4, but can be ordered additionally) Cable between temperature monitoring box and SIPROTEC 4 unit - length 5 m/16.4 ft - length 25 m/82 ft - length 50 m/164 ft
Manual for 7SJ64 English /German

Order No.
7XV5662-2AD10 7XV5662-5AD10
C53207-A401-D76-1 C53207-A401-D77-1
7XV5100-4
7XV5103-7AA05 7XV5103-7AA25 7XV5103-7AA50 C53000-G1100-C147-x 1)

Accessories

LSP2289-afp.eps

10 11

Mounting rail

LSP2091-afp.eps

LSP2090-afp.eps

12 13

2-pin connector

3-pin connector

LSP2092-afp.eps

LSP2093-afp.eps

14 15

Short-circuit links

for current terminals for current terminals

5/80 Siemens SIP · Edition No. 8

1) x = please inquire for latest edition (exact Order No.).

Description

Order No.

Size of package

Supplier

Terminal safety cover

Voltage/current terminal 18-pole/12-pole C73334-A1-C31-1

Voltage/current terminal 12-pole/8-pole

C73334-A1-C32-1

Connector 2-pin

C73334-A1-C35-1

Connector 3-pin

C73334-A1-C36-1

Siemens Siemens Siemens Siemens

Crimp connector CI2 0.5 to 1 mm2

0-827039-1

Crimp connector CI2 0.5 to 1 mm2 Crimp connector: Type III+ 0.75 to 1.5 mm2 Crimp connector: Type III+ 0.75 to 1.5 mm2

0-827396-1 0-163084-2 0-163083-7

Crimping tool for Type III+ and matching female
Crimping tool for CI2 and matching female

0-539635-1 0-539668-2 0-734372-1 1-734387-1

4000

taped on reel

4000

taped on reel

Short-circuit links for current terminals for other terminals

C73334-A1-C33-1

C73334-A1-C34-1

Siemens Siemens

Mounting rail for 19" rack

C73165-A63-D200-1 1

Siemens

1) Your local Siemens representative can inform you on local suppliers.

Overcurrent Protection/7SJ64
Connection diagram

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 5/81

Overcurrent Protection/7SJ64
Connection diagram

14 15

5/82 Siemens SIP · Edition No. 8

Overcurrent Protection/7SJ64
Connection diagram

*) For pinout of communication ports see part 14 of this catalog. For the allocation of the terminals of the panel surface-mounting version refer to the manual (http://www.siemens.com/siprotec).

1) P ower relays are intended to directly control motorized switches. The power relays are interlocked so only one relay of each pair can close at a time, in order to avoid shorting out the power supply. The power relay pairs are BO6/BO7, BO8/BO9. If used for protection purposes only one binary output of a pair can be used.

Fig. 5/86 7SJ642 connection diagram

14 15

Siemens SIP · Edition No. 8 5/83

Overcurrent Protection/7SJ64
Connection diagram

Fig. 5/87 7SJ645 connection diagram

5/84 Siemens SIP · Edition No. 8

*)F or pinout of communication ports see part 14 of this catalog. For the allocation of the terminals of the panel surface-mounting version refer to the manual (http://www.siemens.com/siprotec).
1)P ower relays are intended to directly control motorized switches. The power relays are interlocked so only one relay of each pair can close at a time, in order to avoid shorting out the power supply. The power relay pairs are BO6/BO7, BO8/BO9, BO13/BO14, BO15/BO16. If used for protection purposes only one binary output of a pair can be used.

Overcurrent Protection/7SJ64
Connection diagram

Fig. 5/88 7SJ647 connection diagram part 1; continued on following page

1)P ower relays are intended to directly control motorized switches. The power relays are interlocked so only one relay of each pair can close at a time, in order to avoid shorting out the power supply. The power relay pairs are BO6/BO7, BO8/BO9, BO13/BO14, BO15/BO16. If used for protection purposes only one binary output of a pair can be used.

13 14 15

Siemens SIP · Edition No. 8 5/85

Overcurrent Protection/7SJ64
Connection diagram

14 15

5/86 Siemens SIP · Edition No. 8

SIPROTEC 7SJ66
Description

Protection functions (continued)

· Under-/overvoltage protection · Under-/overfrequency protection

· Rate-of-frequency-change protection

· P ower protection (e.g. reverse, factor)

· U ndervoltage controlled reactive power protection

· Breaker failure protection

· Negative-sequence protection

· Phase-sequence monitoring

· Synchro-check

· Fault locator

· Lockout · Admittance Earth Fault Protection

· Auto-reclosure

Fig. 5/90 SIPROTEC 7SJ66 multifunction protection relay
Description
The SIPROTEC 7SJ66 unit is a numerical protection, control and monitoring device, designed to use in Medium Voltage and Industry applications. SIPROTEC 7SJ66 is featuring the "flexible protection functions". Up to 20 protection functions can be added according to individual requirements. Thus, for example, a rate-of-frequency-change protection or reverse power protection can be implemented. The relay provides control of the circuit-breaker, further switching devices and automation functions. The integrated graphical logic editor (CFC) allows the user to implement its own functions, e. g. for the automation of switchgear (interlocking). The communication interfaces support the easy integration into modern communication networks.
Function overview
Protection functions · Overcurrent protection · Directional overcurrent protection · Sensitive directional ground-fault detection · Displacement voltage · Intermittent ground-fault protection · Directional intermittent ground fault protection · High-impedance restricted ground fault · Inrush restraint · Motor protection · Overload protection · Temperature monitoring

Control functions/programmable logic · Commands f. ctrl of CB and of isolators · Position of switching elements is shown on the graphic display · Control via keyboard, binary inputs, DIGSI 4 or SCADA system · User-defined logic with CFC (e.g. interlocking)
Monitoring functions · Operational measured values V, I, f · Energy metering values Wp, Wq · Circuit-breaker wear monitoring · Slave pointer · Trip circuit supervision · Fuse failure monitor · 8 oscillographic fault records with a sampling rate of 1.6 kHz · Motor statistics · Security log
Communication (build in interfaces) · System interface
IEC 60870-5-103/IEC 61850 / Modbus RTU / DNP3 · Service interface for DIGSI 4/ RTD-Box · Electrical and optical interface · RSTP, PRP (Redundancy Protocol for Ethernet) · Front USB interface for DIGSI 4 · Time synchronization via IRIG B/DCF77
Hardware
· Screw-type current terminals · Spring or Screw-type Voltage and Binary I/O terminals · 4 current and 4 voltage transformers · 16/22/36 binary inputs · 7/10/23 output relays · Graphical or 8 line text display

5 6 7 8 9 10 11 12 13 14

15
Siemens SIP · Edition No. 8 5/87

SIPROTEC 7SJ66
Application

Busbar

2 3 4 5 6

Local/remote control Commands/Feedbacks

74TC Trip circuit supervision

86 Lock out

CFC logic AND

Metering values
Set points Mean value Min/Max-Log

I, V, Watts, Vars,p.f.,f

HMI

Communication interface Electrical: IEC61850

RTD 1) box interface

Energy meter: calculated and/or by impulses

IEC60870-5-103 Modbus RTU Fault recording DNP3

Motor protection

Fault Locator

Restart

Starting Load

inhibit

I< time jam

Optical: IEC61850 DNP3

66/86 37 48 51M

38 14

Bearing Locked Motor temp rotor statistics

I>>, I>>>
50
IE>>, IE>>>
50N

I>,

IE>>,

IE>,

IE>>>

IEp

I2>

50N

51N 46

IE>, IEp
51N

Hight-impedance restricted earth-fault
87N

InRush BLK

Breaker failure

protection

Intermitt. ground flt 50BF

51V

Autoreclosure

25 Synchrocheck

V, f, P

Flexible protection functions P<>, Q<> cos df/dt

55 81R

f<, f>

81U/O

Directional

Phase sequence monitoring

I>> dir. I> dir. Ip dir.
67

IE>> dir. IE> dir. IEp dir.
67N

Dir. Sensitive earth-fault detection

IEE>>,
IEE> IEEp

VE>

67Ns

1) RTD = resistance temperature detector
7

8 9 10 11 12 13 14 15

Fig. 5/91 Function diagram

Application
The SIPROTEC 7SJ66 unit is a numerical protection relay that also performs control and monitoring functions and therefore supports the user in cost-effective power system management. The relay ensures reliable supply of electric power to the customers. Local operation has been designed according to ergonomic criteria. A large, easy-to-read display was a major design aim.
Control
The integrated control function permits control of disconnect devices, grounding switches or circuit-breakers via the integrated operator panel, binary inputs, DIGSI 4 or the control and protection system (e.g. SICAM). The present status (or position) of the primary equipment can be displayed, in case of devices with graphic display. A full range of command processing functions is provided.
Programmable logic
The integrated logic characteristics (CFC) allow the user to implement their own functions for automation of switchgear (interlocking) or a substation via a graphic user interface. The user can also generate user-defined messages.
Line protection
The SIPROTEC 7SJ66 units can be used for line protection of high and medium-voltage networks with earthed (grounded), low-resistance grounded, isolated or compensated neutral point.

Synchro-check
In order to connect two components of a power system, the relay provides a synchro-check function which verifies that switching ON does not endanger the stability of the power system.
Motor protection
When protecting motors, the SIPROTEC 7SJ66 relay is suitable for asynchronous machines of all sizes.
Transformer protection
The relay performs all functions of backup protection supplementary to transformer differential protection. The inrush suppression effectively prevents tripping by inrush currents. The high-impedance restricted ground-fault protection detects short-circuits and insulation faults on the transformer.
Backup protection
The SIPROTEC 7SJ66 can be used universally for backup protection.
Flexible protection functions
By configuring a connection between a standard protection logic and any measured or derived quantity, the functional scope of the relays can be easily expanded by up to 20 protection stages or protection functions.
Metering values
Extensive measured values, limit values and metered values permit improved system management.

5/88 Siemens SIP · Edition No. 8

SIPROTEC 7SJ66
Application

ANSI 50, 50N 50, 51V, 51N 67, 67N
67Ns/50Ns 59N/64
67Ns 87N 50BF 79 25 46 47 49 48 51M 14 66/86 37 38 27, 59 59R 32 27/Q 55 81O/U 81R
21FL

IEC

Protection functions

I>, I>>, I>>>, IE>, IE>>,IE>>> Definite-time overcurrent protection (phase/neutral)

Ip, IEp

Inverse overcurrent protection (phase/neutral), phase function with voltage-dependent option

Idir>, Idir>>, Ip dir IEdir>, IEdir>>, IEp dir
IEE>, IEE>>, IEEp

Directional overcurrent protection (definite/inverse, phase/neutral), Admittance Y0>, Directional comparison protection
Directional/non-directional sensitive ground-fault detection

Cold load pick-up (dynamic setting change)

VE, V0>

Displacement voltage, zero-sequence voltage

IIE> IIE dir>

Intermittent ground fault Directional intermittent ground fault protection

High-impedance restricted ground-fault protection

Breaker failure protection Auto-reclosure

Synchro-check

I2>

Phase-balance current protection (negative-sequence protection)

V2>, phase-sequence

Unbalance-voltage protection and/or phase-sequence monitoring

Thermal overload protection

Starting time supervision

Load jam protection

Locked rotor protection

Restart inhibit

Undercurrent monitoring

Temperature monitoring via external device (RTD-box), e.g. bearing temperature monitoring

V<, V> dV/dt P<>, Q<>

Undervoltage/overvoltage protection Rate-of-voltage-change protection Reverse-power, forward-power protection

Q>/V< cos

Undervoltage-controlled reactive power protection Power factor protection

f>, f< df/dt

Overfrequency/underfrequency protection Rate-of-frequency-change protection

Fault locator

1 2 3 4 5 6 7 8 9 10 11 12

15
Siemens SIP · Edition No. 8.1 5/89

SIPROTEC 7SJ66
Construction, protection functions

Fig. 5/92 SIPROTEC 7SJ66 rear view with

Fig. 5/93 Definite-time overcurrent

optical Ethernet system interfaces protection

Fig. 5/94 Inverse-time overcurrent protection

6 7 8 9 10 11 12 13 14

Construction
Connection techniques and housing with many advantages 1/3-rack size and 1/2-rack size are the available housing widths of the SIPROTEC 7SJ66 relays, referred to a 19" module frame system. This means that previous models can always be replaced. The height is a uniform 244 mm for flush-mounting housing. All CT-cables can be connected with or without ring lugs.
Protection functions
Overcurrent protection (ANSI 50, 50N, 51, 51V, 51N) This function is based on the phase-selective measurement of the three phase currents and the ground current (four transformers). Three definite-time overcurrent protection elements (DMT) exist both for the phases and for the ground. The current threshold and the delay time can be set within a wide range. In addition, inverse-time overcurrent protection characteristics (IDMTL) can be activated. The inverse-time function provides as an option voltagerestraint or voltage-controlled operating modes.

Available inverse-time characteristics

Characteristics acc. to

ANSI/IEEE

Inverse

Short inverse

Long inverse

Moderately inverse

Very inverse

Extremely inverse

IEC 60255-3 ·
·
· ·

5/90 Siemens SIP · Edition No. 8

SIPROTEC 7SJ66
Protection functions

Fig. 5/95 Directional characteristic of the directional overcurrent protection

Fig. 5/96 Directional determination using cosine measurements for compensated networks
(Sensitive) ground-fault detection (ANSI 50Ns, 51Ns / 50N, 51N) For high-resistance grounded networks, a sensitive input transformer is connected to a phase-balance neutral current transformer (also called core-balance CT). The function can also be operated in the insensitive mode as an additional short-circuit protection. It is also possible to detect gound faults with the admittance principle.

1 2 3 4 5 6 7 8 9 10 11 12 13 14

15
Siemens SIP · Edition No. 8 5/91

SIPROTEC 7SJ66
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Directional intermittent ground fault protection (ANSI 67Ns)
The directional intermittent ground fault protection has to detect intermittent ground faults in resonant grounded cable systems selectively. Intermittent ground faults in resonant grounded cable systems are usually characterized by the following properties:
· A very short high-current ground current pulse (up to several hundred amperes) with a duration of under 1 ms
· They are self-extinguishing and re-ignite within one halfperiod up to several periods, depending on the power system condi tions and the fault characteristic.
· Over longer periods (many seconds to minutes), they can develop into static faults.
Such intermittent ground faults are frequently caused by weak insulation, e.g. due to decreased water resistance of old cables. Ground fault functions based on fundamental component measured values are primarily designed to detect static ground faults and do not always behave correctly in case of intermittent ground faults. The function described here evaluates specifi cally the ground current pulses and puts them into relation with the zero-sequence voltage to determine the direction.
Phase-balance current protection (ANSI 46) (Negative-sequence protection)
In line protection, the two-element phase-balance current/ negative-sequence protection permits detection on the high side of high-resistance phase-to-phase faults and phase-to-ground faults that are on the low side of a transformer (e.g. with the switch group Dy 5). This provides backup protection for highresistance faults beyond the transformer.
Breaker failure protection (ANSI 50BF)
If a faulted portion of the electrical circuit is not disconnected upon issuance of a trip command, another command can be initiated using the breaker failure protection which operates the circuit-breaker, e.g. of an upstream (higher-level) protection relay. Breaker failure is detected if, after a trip command, current is still flowing in the faulted circuit. As an option, it is possible to make use of the circuit-breaker position indication.

Fig. 5/97 High-impedance restricted ground-fault protection
High-impedance restricted ground-fault protection (ANSI 87N)
The high-impedance measurement principle is an uncomplicated and sensitive method for detecting ground faults, especially on transformers. It can also be applied to motors, generators and reactors when these are operated on an grounded network.
When the high-impedance measurement principle is applied, all current transformers in the protected area are connected in parallel and operated on one common resistor of relatively high R whose voltage is measured (see Fig. 5/134). In the case of 7SJ6 units, the voltage is measured by detecting the current through the (external) resistor R at the sensitive current measurement input IEE. The varistor V serves to limit the voltage in the event of an internal fault. It cuts off the high momentary voltage spikes occurring at transformer saturation. At the same time, this results in smoothing of the voltage without any noteworthy reduction of the average value.
If no faults have occurred and in the event of external faults, the system is at equilibrium, and the voltage through the resistor is approximately zero. In the event of internal faults, an imbalance occurs which leads to a voltage and a current flow through the resistor R.
The current transformers must be of the same type and must at least offer a separate core for the high-impedance restricted ground-fault protection. They must in particular have the same transformation ratio and an approximately identical knee-point voltage. They should also demonstrate only minimal measuring errors.

15
5/92 Siemens SIP · Edition No. 8

SIPROTEC 7SJ66
Protection functions

Flexible protection functions
The SIPROTEC 7SJ66 units enable the user to easily add on up to 20 protective functions. To this end, parameter definitions are used to link a standard protection logic with any chosen characteristic quantity (measured or derived quantity). The stand- ard logic consists of the usual protection elements such as the pickup message, the parameter-definable delay time, the TRIP command, a blocking possibility, etc. The mode of operation for current, voltage, power and power factor quantities can be three-phase or single-phase. Almost all quantities can be operated as greater than or less than stages. All stages operate with protection priority.
Protection stages/functions attainable on the basis of the available characteristic quantities:

Function I>, IE> V<, V>, VE>, dV/dt 3I0>, I1>, I2>, I2/I1, 3V0>, V1><, V2><, Q>< cos (p.f.)>< f><
df/dt><

ANSI No. 50, 50N 27, 59, 59R, 64 50N, 46, 59N, 47 32 55 81O, 81U
81R

dv /dt
LSA4113-aen.eps
Fig. 5/98 Flexible protection functions
· Starting of the ARC depends on the trip command selection (e.g. 46, 50, 51, 67)
· Blocking option of the ARC via binary inputs · ARC can be initiated externally or via CFC · The directional and non-directional elements can either be
blocked or operated non-delayed depending on the autoreclosure cycle · Dynamic setting change of the directional and non-directional elements can be activated depending on the ready AR
Thermal overload protection (ANSI 49)
For protecting cables and transformers, an overload protection with an integrated pre-warning element for temperature and current can be applied. The temperature is calculated using a thermal homogeneous-body model (according to IEC 60255-8), which takes account both of the energy entering the equipment and the energy losses. The calculated temperature is constantly adjusted accordingly. Thus, account is taken of the previous load and the load fluctuations.
For thermal protection of motors (especially the stator) a further time constant can be set so that the thermal ratios can be detected correctly while the motor is rotating and when it is stopped. The ambient temperature or the temperature of the coolant can be detected serially via an external temperature monitoring box (resistance-temperature detector box, also called RTD-box). The thermal replica of the overload function is automatically adapted to the ambient conditions. If there is no RTD-box it is assumed that the ambient temperatures are constant.
Settable dropout delay times
If the devices are used in parallel with electromechanical relays in networks with intermittent faults, the long dropout times of the electromechanical devices (several hundred milliseconds) can lead to problems in terms of time grading. Clean time grading is only possible if the dropout time is approximately the same. This is why the parameter of dropout times can be defined for certain functions such as time-over-current protection, ground short-circuit and phase-balance current protection.

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 5/93

SIPROTEC 7SJ66
Protection functions

1 2 3 4 5 6 7 8 9 10 11

12 13 14 15

Motor protection

Temperature monitoring (ANSI 38)

One temperature monitoring box with a total of 12 measuring sensors can be used

Fig. 5/99

for temperature monitoring and detection

by the protection relay. The thermal status of motors, generators

and transformers can be monitored with this device. Addition-

ally, the temperature of the bearings of rotating machines are

monitored for limit value violation. The temperatures are being

measured with the help of temperature detectors at various

locations of the device to be protected. This data is transmitted

to the protection relay via one or two temperature monitoring

boxes (see "Accessories", page 5/115).

for I > IMOTOR START

I A I

= Actual current flowing

IMOTOR START = Pickup current to detect a motor start

= Tripping time

= Rated motor starting current

= Tripping time at rated motor starting current

(2 times, for warm and cold motor)

5/94 Siemens SIP · Edition No. 8

SIPROTEC 7SJ66
Protection functions

wide frequency range (25 to 70 Hz). Even when falling below this frequency range the function continues to work, however, with a greater tolerance band.
The function can operate either with phase-to-phase, phase-toground or positive phase-sequence voltage and can be monitored with a current criterion. Three-phase and single-phase connections are possible.
Frequency protection (ANSI 81O/U)
Frequency protection can be used for over- frequency and underfrequency protection. Electric machines and parts of the system are protected from unwanted speed deviations. Unwanted frequency changes in the network can be detected and the load can be removed at a specified frequency setting.
There are four elements (select- able as overfrequency or underfrequency) and each element can be delayed separately. Blocking of the frequency protection can be performed if using a binary input or by using an undervoltage element.
Fault locator (ANSI 21FL)
The integrated fault locator calculates the fault impedance and the distance-to-fault. The results are displayed in , kilometers (miles) and in percent of the line length.
Circuit-breaker wear monitoring
Methods for determining circuit-breaker contact wear or the remaining service life of a circuit-breaker (CB) allow CB maintenance intervals to be aligned to their actual degree of wear. The benefit lies in reduced maintenance costs.
There is no mathematically exact method of calculating the wear or the remaining service life of circuit-breakers that takes into account the arc-chamber's physical conditions when the CB opens. This is why various methods of determining CB wear have evolved which reflect the different operator philosophies. To do justice to these, the devices offer several methods:
· I · Ix, with x = 1... 3 · i2t
The devices additionally offer a new method for determining the remaining service life:
· Two-point method
The CB manufacturers double-logarithmic switching cycle diagram (see Fig. 5/137) and the breaking current at the time of contact opening serve as the basis for this method. After CB opening, the two-point method calculates the number of still possible switching cycles. To this end, the two points P1 and P2 only have to be set on the device. These are specified in the CB's technical data.
All of these methods are phase-selective and a limit value can be set in order to obtain an alarm if the actual value falls below or exceeds the limit value during determination of the remaining service life.
Customized functions (ANSI 32, 51V, 55, etc.)
Additional functions, which are not time critical, can be implemented via the CFC using measured values. Typical functions include reverse power, voltage controlled overcurrent, phase angle detection, and zero-sequence voltage detection.

Fig. 5/100 CB switching cycle diagram
Commissioning Commissioning could hardly be easier and is fully supported by DIGSI 4. The status of the binary inputs can be read individually and the state of the binary outputs can be set individually. The operation of switching elements (circuit-breakers, disconnect devices) can be checked using the switching functions of the bay controller. The analog measured values are represented as wideranging operational measured values. To prevent transmission of information to the control center during maintenance, the bay controller communications can be disabled to prevent unnecessary data from being transmitted. During commissioning, all indications with test marking for test purposes can be connected to a control and protection system.
Test operation During commissioning, all indications can be passed to an automatic control system for test purposes.
Control and automatic functions
Control In addition to the protection functions, the SIPROTEC 4 units also support all control and monitoring functions that are required for operating medium-voltage or high-voltage substations.
The main application is reliable control of switching and other processes.
The status of primary equipment or auxiliary devices can be obtained from auxiliary contacts and communicated to the SIPROTEC 7SJ66 via binary inputs. Therefore it is possible to detect and indicate both the OPEN and CLOSED position or a fault or intermediate circuit-breaker or auxiliary contact position.
The switchgear or circuit-breaker can be controlled via: integrated operator panel binary inputs substation control and protection system DIGSI 4

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 5/95

SIPROTEC 7SJ66
Functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Fig. 5/101 SIPROTEC 7SJ663 rear view with communication ports
Switchgear cubicles for high/medium voltage All units are designed specifically to meet the requirements of high/medium-voltage applications. In general, no separate measuring instruments (e.g., for current, voltage, frequency, ...) or additional control components are necessary.
Measured values The r.m.s. values are calculated from the acquired current and voltage along with the power factor, frequency, active and reactive power. The following functions are available for measured value processing: · Currents IL1, IL2, IL3, IE, IEE (67Ns) · Voltages VL1, VL2, VL3, VL1L2, VL2L3, VL3L1 · Symmetrical components I1, I2, 3I0; V1, V2, V0 · Power Watts, Vars, VA/P, Q, S (P, Q: total and phase selective) · Power factor (cos ), (total and phase selective) · Frequency · Energy ± kWh, ± kVarh, forward and reverse power flow · Mean as well as minimum and maximum current and voltage
values · Operating hours counter · Mean operating temperature of overload function · Limit value monitoring
Limit values are monitored using programmable logic in the CFC. Commands can be derived from this limit value indication. · Zero suppression In a certain range of very low measured values, the value is set to zero to suppress interference.

7SJ66_breit_W11.png

5/96 Siemens SIP · Edition No. 8

SIPROTEC 7SJ66
Communication

Communication

In terms of communication, the units offer substantial flexibility in the context of connection to industrial and power automation standards.

USB interface
There is a USB interface on the front of the relay. All the relay functions can be parameterized on PC by using DIGSI. Commissioning tools and fault analysis are built into the DIGSI program and are used through this interface.

Rear interfaces
· Time synchronization interface All units feature a permanently integrated electrical time synchronization interface. It can be used to feed timing telegrams in IRIG-B or DCF77 format into the units via time synchronization receivers.
· System interface Communication with a central control system takes place through this interface. The units can exchange data through this interface via Ethernet and IEC 61850 protocol and can also be operated by DIGSI.
· Service interface The service interface was conceived for remote access to a number of protection units via DIGSI. It also allows communication via modem. For special applications, a temperature monitoring box (RTD box) can be connected to this interface.

Fig. 5/102 IEC 60870-5-103: Radial electrical connection

System interface protocols

IEC 61850 protocol
The Ethernet-based IEC 61850 protocol is the worldwide standard for protection and control systems used by power supply corporations. Siemens was the first manufacturer to support this standard. By means of this protocol, information can also be exchanged directly between bay units so as to set up simple masterless systems for bay and system interlocking. Access to the units via the Ethernet bus is also possible with DIGSI.
IEC 60870-5-103 protocol
The IEC 60870-5-103 protocol is an international standard for the transmission of protective data and fault recordings. All messages from the unit and also control commands can be transferred by means of published, Siemens-specific extensions to the protocol.
Redundant solutions are also possible. Optionally it is possible to read out and alter individual parameters (only possible with the redundant module).

Fig. 5/103 B us structure for station bus with Ethernet and IEC 61850, electrical and optical ring
DNP3 DNP (Distributed Network Protocol, version 3) is a messagingbased communication protocol. SIPROTEC 7SJ66 is fully Level 1 and Level 2-compliant with DNP3, which is supported by a number of protection units manufactures.

Modbus RTU protocol
This serial protocol is mainly used in industry and by power supply corporations, and is supported by a number of unit manufacturers. SIPROTEC units function as Modbus slaves, making their information available to a master or receiving information from it. A time-stamped event list is available.

1 2 3 4 5 6 7 8 9 10 11 12 13 14

15
Siemens SIP · Edition No. 8 5/97

SIPROTEC 7SJ66
Selection table

1 2 3 4 5 6 7 8 9 10 11 12

Selection table for multifunctional overcurrent protection devices

Device

7SJ80

7SJ61

7SJ62

7SJ63

7SJ64

7SJ82

7SJ66

Multifunctional protection

functions

CTs

VTs

0/3

3/4

0/4

Binary inputs incl. Life contact

3 - 11

8 - 11

11 - 37

7 - 48

11 - 23

16 - 36

Binary outputs

5 - 9

4 - 9

6 - 9

8 - 19

5 - 26

8 - 16

7 - 24

Spring-type terminals

Auxiliary voltage

DC 24 - 250 V DC 24 - 250 V DC 24 - 250 V DC 24 - 250 V DC 24 - 250 V DC 24 - 250 V DC 110 - 250 V AC 115 - 230 V AC 115 - 230 V AC 115 - 230 V AC 115 - 230 V AC 115 - 230 V AC 115 - 230 V AC 115 - 230 V

UL listing

Surface mounting case

Detached on-site operation panel

Languages

ge/en/es/fr/it/ ru/ch

Front USB

ge/en/es/fr/it/ru ge/en/es/fr/it/ru

l ge/en/es/fr
-

ge/en/es/fr/it/ru ge/en/pt/es/ru

en/es/ru/pl/tr
ü

Interfaces exchangeable

IEC 61850

IEC 60870-5-103

l (elec.)

Modbus RTU

l (elec.)

PROFIBUS FMS

PROFIBUS DP

PROFINET I/O

DNP3 serial/TCP

RSTP

PRP

HSR

ü basic - not available l optional

15
5/98 Siemens SIP · Edition No. 8.1

Typical connections
Connection of current and voltage transformers Standard connection For grounded networks, the ground current is obtained from the phase currents by the residual current circuit.

SIPROTEC 7SJ66
Typical connections
1 2 3

Fig. 5/104 Residual current circuit without directional element

7
Fig. 5/105 Sensitive ground-current detection without directional element
8

Fig. 5/106 Residual current circuit with directional element

12 13

15
Siemens SIP · Edition No. 8.1 5/99

SIPROTEC 7SJ66
Typical connections

Connection for compensated networks

The figure shows the connection of two phase-to-ground voltages and the

VE voltage of the open delta winding

and a phase-balance neutral current

transformer for the ground current. This connection maintains maximum precision

for directional ground-fault detection and

must be used in compensated networks.

Fig. 5/144 shows sensitive directional

ground-fault detection.

Fig. 5/107 Sensitive directional ground-fault detection with directional element for phases

Connection for isolated-neutral or compensated networks only

If directional ground-fault protection is

not used, the connection can be made

with only two phase current transformers. Directional phase short-circuit protection

can be achieved by using only two

primary transformers.

10 11 12

Fig. 5/108 Isolated-neutral or compensated networks

14 15
5/100 Siemens SIP · Edition No. 8.1

Fig. 5/109 Measuring of the busbar voltage and the outgoing feeder voltage for the synchro-check

SIPROTEC 7SJ66
Typical applications

Overview of connection types

Type of network

Function

Current connection

Voltage connection

(Low-resistance) grounded network Overcurrent protection

Residual circuit, with 3 phase-current

phase/ground non-directional transformers required, phase-balance

neutral current transformer possible

(Low-resistance) grounded networks Sensitive ground-fault protection Phase-balance neutral current

transformers required

Isolated or compensated networks Overcurrent protection phases Residual circuit, with 3 or 2 phase

non-directional

current transformers possible

(Low-resistance) grounded networks Overcurrent protection

Residual circuit, with 3 phase-current Phase-to-ground connection or

phases directional

transformers possible

phase-to-phase connection

Isolated or compensated networks Overcurrent protection phases directional
(Low-resistance) grounded networks Overcurrent protection ground directional

Isolated networks

Sensitive ground-fault protection

Residual circuit, with 3 or 2 phase-

Phase-to-ground connection or

current transformers possible

phase-to-phase connection

Residual circuit, with 3 phase-current Phase-to-ground connection required

transformers required, phase-balance

neutral current transformers possible

Residual circuit, if ground current

3 times phase-to-ground connection or

> 0.05 IN on secondary side, otherwise phase-to-ground connection with open

phase-balance neutral current

delta winding

transformers required

Compensated networks

Sensitive ground-fault p rotection Phase-balance neutral current

cos measurement

transformers required

Phase-to-ground connection with open delta winding required

Typical applications

Connection of circuit-breaker

Undervoltage releases
Undervoltage releases are used for automatic tripping of high-voltage motors.
Example: DC supply voltage of control system fails and manual electric tripping is no longer possible.
Automatic tripping takes place when voltage across the coil drops below the trip limit. In Fig. 5/147, tripping occurs due to failure of DC supply voltage, by automatic opening of the live status contact upon failure of the protection unit or by shortcircuiting the trip coil in event of network fault.
In Fig. 5/148 tripping is by failure of auxiliary voltage and by interruption of tripping circuit in the event of network failure. Upon failure of the protection unit, the tripping circuit is also interrupted, since contact held by internal logic drops back into open position.

Fig. 5/110 Undervoltage release with make contact (50, 51)

7 8 9 10 11 12 13 14

Fig. 5/111 Undervoltage trip with locking contact (trip signal 50 is inverted)

Siemens SIP · Edition No. 8 5/101

SIPROTEC 7SJ66
Typical applications

Trip circuit supervision (ANSI 74TC)

One or two binary inputs can be used for monitoring the circuit-breaker trip coil

including its incoming cables. An alarm

signal occurs whenever the circuit is

interrupted.

Lockout (ANSI 86)

All binary outputs can be stored like LEDs

and reset using the LED reset key. The lockout state is also stored in the event of

supply voltage failure. Reclosure can only

occur after the lockout state is reset.

Reverse-power protection for dual supply (ANSI 32R)

If power is fed to a busbar through two

parallel infeeds, then in the event of any

fault on one of the infeeds it should be

selectively interrupted. This ensures a

Fig. 5/112 Trip circuit supervision with 2 binary inputs

continued supply to the busbar through

the remaining infeed. For this purpose,

directional devices are needed which detect a short-circuit current or a power

flow from the busbar in the direction of

the infeed. The directional overcurrent

protection is usually set via the load current. It cannot be used to deactivate

low-current faults. Reverse-power

protection can be set far below the rated

power. This ensures that it also detects power feedback into the line in the event

of low-current faults with levels far below

the load current.

Reverse-power protection is performed via

the "flexible protection functions" of the SIPROTEC 7SJ66.

10 11

Fig. 5/113 Reverse-power protection for dual supply

15
5/102 Siemens SIP · Edition No. 8

SIPROTEC 7SJ66
Selection and ordering data

Description
SIPROTEC 7SJ66 multifunction protection relay and bay controller Housing, inputs, outputs Housing 1/3 19", 4 x U, 4 x I, 16 BI, 7 BO, 1 life contact Housing 1/3 19", 4 x U, 4 x I, 22 BI, 10 BO, 1 life contact Housing 1/2 19", 4 x U, 4 x I, 36 BI, 23 BO, 1 life contact, 4 function keys

Order No. 12345 6 7 8 9 101112 13141516 171819 7SJ66 - - -
1 2 3

Measuring inputs

Iph = 1 A, IN = 1 A (min. = 0.05 A)

Position 15 only with A, C, E, G

Iph = 1 A, IN = sensitive (min. = 0.001 A)

Position 15 only with B, D, F, H

Iph = 5 A, IN = 5 A (min. = 0.25 A)

Position 15 only with A, C, E, G

Iph = 5 A, IN = sensitive (min. = 0.001 A)

Position 15 only with B, D, F, H

Rated auxiliary voltage (power supply, indication voltage)

DC 24 to 48 V, threshold binary input DC 19 V 3)

DC 110 to 250 V, AC 115 to 230 V, threshold binary input DC 88 V

DC 110 to 250 V, AC 115 to 230 V, threshold binary input DC 176V

Construction

Flush-mounting case, screw-type terminals, 8-line text display

Flush-mounting case, spring-type terminals (direct connection), screw-type terminals for CT connec-

tion (direct connection/ring-type cable lugs), 8-line text display

Flush-mounting case, screw-type terminals, graphical display

Flush-mounting case, spring-type terminals (direct connection),

screw-type terminals for CT connection (direct connection/ring-type cable lugs), graphical display

Region-specific default settings/function versions and language settings Region World, 50/60 Hz, IEC/ANSI, language: English (language can be changed) Region World, 50/60 Hz, IEC/ANSI, language: Spanish (language can be changed) Region RU, 50/60 Hz, IEC/ANSI, language: Russian (language can be changed)
System interface (Port B) No system interface IEC 60870-5-103, electrical RS485, RJ45-connector 1) Modbus RTU, electrical RS485, RJ45-connector 1) DNP3, RS485 1) IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45-connector 2) IEC 61850, 100 Mbit Ethernet, optical, double, LC-connector 2) DNP3 + IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45-connector 2) DNP3 + IEC 61850, 100 Mbit Ethernet, optical, double, LC-connector 2)
Service interface (Port C) No interface DIGSI 4/Modem/RTD-box, electrical RS485, RJ45-connector Ethernet port (DIGSI port, RTD box connection, not IEC 61850), RJ45-connector
Functionality See next page

B E G

L 0 D

L 0 G

L 0 R

L 0 S

L 2 R

L 2 S

0 2 6
Continued on next page

1) only available with position 12 = 0 or 2 2) only available with position 12 = 0 or 6 3) only available with position 6 = 1

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8.1 5/103

SIPROTEC 7SJ66
Selection and ordering data

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Description

Order No.

Order code

Multifunction protection relay with local control

12345 6 7 8 9 101112 13141516 171819 7SJ66 - - -

ANSI No.

Basic version

Control

F A

50/51

Overcurrent protection I>, I>>, I>>>, Ip

50N/51N Ground-fault protection IE>, IE>>, IE>>>, IEp

50N/51N Insensitive ground-fault protection via

IEE function: IEE>, IEE>>, IEEp1)

50/50N Flexible protection functions (index quantities

derived from current): Additional time-overcurrent

protection stages I2>, I>>>>, IE>>>>

51 V

Voltage-dependent inverse-time overcurrent protection

Overload protection (with 2 time constants)

Phase balance current protection

(negative-sequence protection)

Undercurrent monitoring

Phase sequence

59N/64 Displacement voltage

50BF

Breaker failure protection

74TC

Trip circuit supervision, 4 setting groups, cold-load pickup

Inrush blocking

Lockout

Basic+

Basic version (see above), Intermittent earth-fault

F E

V,P,f

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27Q

Undervoltage-controlled reactive power protection

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Basic +

Basic version (see above)

P E

V,P,f IEF

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27Q

Undervoltage-controlled reactive power protection

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Basic +

Basic version (see above)

F C

Dir

67/67N Direction determination for overcurrent, phases and

ground

Basic +

Basic version (see above)

F G

Dir V,P,f

67/67N Direction determination for overcurrent, phases and

ground

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27Q

Undervoltage-controlled reactive power protection

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Basic +

Basic version (see above)

P G

Dir V,P,f IEF

67/67N Direction determination for overcurrent, phases and

ground

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27Q

Undervoltage-controlled reactive power protection

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Basic +

Basic version (see above)

P C

Dir IEF

67/67N Direction determination for overcurrent, phases and

ground

V, P, f = Voltage, power, frequency protection Dir = Directional overcurrent protection IEF = Intermittent ground fault

1) only with position 7 = 1 or 5 (non-sensitive ground current input)

Continued on next page

5/104 Siemens SIP · Edition No. 8

SIPROTEC 7SJ66
Selection and ordering data

Description

Multifunction protection relay with local control

Basic +
Sens.earth-f-det. Dir REF2)

ANSI No.
67/67N
67Ns 67Ns 87N

Basic version included Direction determination for overcurrent, phases and ground Directional sensitive ground-fault detection Directional intermittent ground fault protection High-impedance restricted earth fault

Order No.

Order code

12345 6 7 8 9 101112 13141516 171819 7SJ66 - - -

F D

P D

Basic + Sens.earth-f-det. Dir IEF REF2)

67/67N

Basic version included Direction determination for overcurrent,

phases and ground

67Ns

Directional sensitive ground-fault detection

67Ns

Directional intermittent ground fault protection

87N

High-impedance restricted ground fault

Intermittent earth-fault

F F

Basic + Dir. Sens.earth-f-det.

Basic version included

V,P,f REF2)

67Ns

Directional sensitive ground-fault detection

67Ns

Directional intermittent ground fault protection

87N

High-impedance restricted ground fault

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27Q

Undervoltage-controlled reactive power protection

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Basic + Dir. Sens.earth-f-det.

Basic version included

F B

REF2)

67Ns

Directional sensitive ground-fault detection

67Ns

Directional intermittent ground fault protection

87N

High-impedance restricted ground fault

Basic + Dir. Sens.earth-f-det.

Basic version included

H F

Motor V,P,f REF2)

67Ns

Directional sensitive ground-fault detection

67Ns

Directional intermittent ground fault protection

87N

High-impedance restricted ground fault

48/14

Starting ime supervision, locked rotor

66/86

Restart inhibit

51M

Motor load jam protection

Motor statistics

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27Q

Undervoltage-controlled reactive power protection

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Basic + Sens.earth-f-det.

Basic version included

H H

Motor Dir V,P,f REF2)

67/67N Direction determination for overcurrent,

phases and ground

67Ns

Directional sensitive ground-fault detection

67Ns

Directional intermittent ground fault protection

87N

High-impedance restricted ground fault

48/14

Starting ime supervision, locked rotor

66/86

Restart inhibit

51M

Motor load jam protection

Motor statistics

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27Q

Undervoltage-controlled reactive power protection

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

V, P, f = Voltage, power, frequency protection Dir = Directional overcurrent protection IEF = Intermittent ground fault

REF Motor

= Restricted earth fault = Motor protection

Continued on next page

2) F or isolated/compensated networks, only with postition 7=2,6 (sensitive earth current input)

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 5/105

SIPROTEC 7SJ66
Selection and ordering data

1 2 3 4 5 6 7 8 9 10 11 12

Description

SIPROTEC 7SJ66 multifunction protection relay and bay controller

ANSI No. Description

Basic + Dir. S.EF Motor2)

Basic version included

67/67N Direction determination for overcurrent,

phases and ground

67Ns

Directional sensitive ground-fault detection

67Ns

Directional intermittent ground fault protection

87N

High-impedance restricted ground fault

48/14

Starting ime supervision, locked rotor

66/86

Restart inhibit

51M

Motor load jam protection

Motor statistics

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27Q

Undervoltage-controlled reactive power protection

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

Order No.

Order code

12345 6 7 8 9 101112 13141516 171819 7SJ66 - -

R H

Basic + Motor Dir V,P,f
Basic + Motor

Basic version included

67/67N Direction determination for overcurrent,

phases and ground

48/14

Starting ime supervision, locked rotor

66/86

Restart inhibit

51M

Motor load jam protection

Motor statistics

27/59

Under-/overvoltage

81O/U

Under-/overfrequency

27Q

Undervoltage-controlled reactive power protection

27/47/59(N) Flexible protection (index quantities derived from

32/55/81R current and voltages): Voltage, power, p.f.,

rate-of-frequency-change protection

48/14 66/86 51M

Basic version included Starting ime supervision, locked rotor Restart inhibit Motor load jam protection Motor statistics

Measuring/fault recording With fault recording Slave pointer, average values, min/max-values with fault recording

79 21FL 79,21FL
25 25, 79, 21FL

ARC, fault locator, synchro-check without
with autoreclose
with fault locator
with 79 and fault locator with synchro-check 3) with synchro-check 3), with auto reclose, with fault recorder

Conformal Coating

H G
H A
13 1 3
16
0 1 2 3 4 7
Z Y 1 3

14 15

Motor = Motor protection V, P, f = Voltage, power, frequency protection Dir = Directional overcurrent protection IEF = Intermittent ground fault

5/106 Siemens SIP · Edition No. 8.1

2) Only with position 7 = 2, 6 (sensitive earth current input). 3) Synchrocheck (no asynchronous switching), one function group

Accessories

SIPROTEC 7SJ66
Selection and ordering data

Description
RTD-Box (Resistance Temperature Detector) RTD box, VH = 24 to 240 V AC/DC RTD box Eth, VH = 24 to 240 V AC/DC
Mounting Rail for 19"-Racks Angle Strip (Mounting Rail)

Order No.
1
7XV5662-6AD10 7XV5662-8AD10

53207-A406-D280-1

Lithium Battery 3 V/1 Ah, Type CR 1/2 AA

VARTA Panasonic

6127 101,301 BR-1/2AA

Varistor (Voltage-Limiting Resistor for High-Impedance

Differential Protection)

125 Veff, 600 A, 1S/S256 240 Veff, 600 A, 1S/S1088

W73028-V3125-A1

W73028-V3300-A2

Screw Cover Screw Cover
Front Unit with Display and HMI Front unit with display and HMI 1/3 Front unit with display and HMI 1/2
USB Cover USB Cover

C53207-A406-D278-1

C53207-A406-D276-1
C53207-A406-D277-1
6
C53207-A406-D271-1

Terminals Terminal voltage,12 pin spring type Terminal voltage,16 pin spring type Terminal voltage,12 pin screw type Terminal voltage,16 pin screw type

C53207-A406-D272-1

C53207-A406-D273-1

C53207-A406-D274-1

C53207-A406-D275-1

1) x = please inquire for latest edition (exact Order No.)

14 15
Siemens SIP · Edition No. 8.1 5/107

SIPROTEC 7SJ66
Connection diagram

R1 Q2

R2 Q2

F2 F3

F6 F5

F8 F9

F11

F12
10 F10

K2
11 K3 K4

12 K6 K7

13 K9 K10

IA
IB
IC
IN/INs
VA VB VC

BI1

BI2

BI3

BI4

BI5

BI6

BI7

BI8

BI9

BI10

BI11

BI12

BI13

BI14

BI15

BI16

Fig. 5/114 SIPROTEC 7SJ661 connection diagram

5/108 Siemens SIP · Edition No. 8

BO1 BO2
BO3 BO4 BO5 BO6
BO7

P3 P4 P5 P6

P11

P12

P10

K11

K13

K12

Life contact

K15

K16

=+
Power Supply = (~) -

P1 P2

System Interface RJ45

Service interface RJ45

Time Synchronization RJ45

Front PC Interface USB

Grounding on the Rear Wall

SIPROTEC 7SJ66
Connection diagram

Q1 Q2 Q3 Q4 Q5 Q6 Q7 Q8
R1 Q2 R2 Q2 R3 R4
R5 R6
F1 F2 F3 F4 F6 F5 F7 F8 F9 F11 F12 F10 K1 K2 K3 K4 K5 K6 K7 K8 K9 K10 J1 J2 J3 J4 J5 J6 J7

IA IB IC IN/INs
VA VB VC
V4

BI1

BI2

BI3

BI4

BI5

BI6

BI7

BI8

BI9

BI10

BI11

BI12

BI13

BI14

BI15

BI16

BI17

BI18

BI19

BI20

BI21

BI22

BO1 BO2
BO3 BO4
BO5 BO6
BO7
BO8 BO9
12
BO10 32

P3 P4 P5 P6
R7 P7 R7 P8
P9
R7 P11 R7 P12
P10 R7 K11 R7 K13
K12
R7 J8 R7 J9
J10
J11 J12

Life contact

R7 K15 K16

=+
Power Supply = (~) -

P1 P2

System Interface RJ45

Service interface RJ45

Time Synchronization RJ45

Front PC Interface USB

Grounding on the Rear Wall

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Fig. 5/115 SIPROTEC 7SJ662 connection diagram

15
Siemens SIP · Edition No. 8 5/109

SIPROTEC 7SJ66
Connection diagram

1 2 3 4 5 6 7 8 9 10 11 12 13

Q1 Q2 Q3 Q4 Q5 Q6 Q7 Q8
R1 Q2 R2 Q2 R3 R4
R5 R6
F1 F2 F3 F4 F5 F6 F7 F8 F9 F10 F11 F12 K1 K2 K3 K4 H1 H2 H3 H4 H5 H6 H7 H8 H9

IA
IB
IC
IN/INs
VA VB VC

BI1

BI2

BI3

BI4

BI5

BI6

BI7

BI8

BI9

BI10

BI11

BI12

BI13

BI14

BI15

BI16

BI17

BI18

BI19

BI20

1 Continue Next Figure

Fig. 5/116 SIPROTEC 7SJ663 connection diagram

5/110 Siemens SIP · Edition No. 8

BO1 BO2
BO3 BO4
BO5 BO6 BO7 BO8 BO9
Life contact

P3 P4 P5 P6

R7 P7

R7 P11

R7 P12

P10

R7 K8

K10

R7 L14 R7 L15
L16

Power Supply

(=~)

+
-

P1 P2

System Interface RJ45

Service interface RJ45

Time Synchronization RJ45

Front PC Interface USB

Grounding on the Rear Wall

2 Continue Next Figure

Continue from Previous Figure 1

H10

BI21

H11

BI22

H12

M1 M2

BI23

M3 M4

BI24

BI25

BI26

BI27

BI28

BI29

BI30

BI31

BI32

G10

BI33

G11

BI34

G12

L1 L2

BI35

L3 L4

BI36

Fig. 5/117 SIPROTEC 7SJ663 connection diagram

SIPROTEC 7SJ66
Connection diagram

Continue from Previous

Figure

BO10 BO11
BO12
BO13 BO14 BO15
BO16 BO17
BO18
BO19 BO20 BO21
BO22 BO23

R7 K11

R7 K13

K12

R7 K14

R7 K15

K16

R7 M8

R7 M9 M10

R7 M11

R7 M13

M12

R7 M14 R7 M15

M16

R7 L8

L10

R7 L11

R7 L13

L12

15
Siemens SIP · Edition No. 8 5/111

SIPROTEC 7SJ66
Dimensions

29.5

172

Mounting Plate
2

244

266

6 Side View
7
146+2
8

Ø6

245 +1

255.8 ± 0.3

Ø5

5.4

12 13 14

13.2

105 ±0.3

7.3

131.5 ±0.3

Dimensional Drawing (Front View)

Fig. 5/118 Dimensional drawing for SIPROTEC 7SJ66 (housing size 1/3)

5/112 Siemens SIP · Edition No. 8

150 145

A B C D

Rear View

266 244
`

29.5

172

Mounting Plate

Side View

221

7.3

206.5

180

Ø6

255.8 5.4
245

Ø5 or M4
13.2 Dimensional Drawing (Front View)
Fig. 5/119 Dimensional drawing of a SIPROTEC 7SJ66 (housing size 1/2)

SIPROTEC 7SJ66
Dimensions

225 220
Rear View

Dimensions in mm

15
Siemens SIP · Edition No. 8 5/113

SIPROTEC 7SJ66
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
5/114 Siemens SIP · Edition No. 8

Distance Protection
Page

SIPROTEC 7SA6 distance protection relay for all voltage levels
SIPROTEC 7SA522 distance protection relay for transmission lines

6/3 6/39

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
6/2 Siemens SIP · Edition No. 8

Distance Protection 7SA6
SIPROTEC 7SA6 distance protection relay for all voltage levels

Fig. 6/1 SIPROTEC 7SA6 distance protection relay
Description
The SIPROTEC 7SA6 distance protection relay is a universal device for protection, control and automation on the basis of the SIPROTEC 4 system. Its high level of flexibility makes it suitable to be implemented at all voltage levels. With this relay you are ideally equipped for the future: it offers security of investment and also saves on operating costs.
High-speed tripping time
Impedance setting range allows very small settings for the protection of very short lines
Self-setting detection for power swing frequencies up to 7 Hz
Current transformer saturation detector prevents non-selective tripping by distance protection in the event of CT saturation.
Phase-segregated teleprotection for improved selectivity and availability
Digital relay-to-relay communication by means of an integrated serial protection data interface
Adaptive auto-reclosure (ADT)

LSP2318-afp.tif

Function overview
Protection functions · Non-switched distance protection with
6 measuring systems (21/21N) · High resistance ground-fault protection
for single and three-pole tripping (50N, 51N, 67N) · Ground-fault detection in isolated and resonant-grounded networks · Tele (pilot) protection (85) · Fault locator (FL) · Power-swing detection/tripping (68/68T) · Phase overcurrent protection (50/51/67) · Switch-onto-fault protection (50HS) · STUB bus overcurrent protection (50STUB) · Overvoltage/undervoltage protection (59/27) · Over/underfrequency protection 81O/U) · Auto-reclosure (79) · Synchro-check (25) · Breaker failure protection (50BF) · Thermal overload protection (49)
Control function · Commands for control of CBs and isolators
Monitoring functions · Trip circuit supervision (74TC) · Self-supervision of the relay · Measured-value supervision · Event logging/fault logging · Oscillographic fault recording · Switching statistics
Front design · Easy operation with numeric keys · Function keys · LEDs for local alarm · PC front port for convenient relay setting
Communication interfaces · Front interface for connecting a PC · System interface for connecting to a control system via vari-
ous protocols IEC 61850 Ethernet IEC 60870-5-103 protocol PROFIBUS DP DNP 3 · 1 serial protection data interface for teleprotection · Rear-side service/modem interface · Time synchronization via IRIG-B or DCF 77 or system interface

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Siemens SIP · Edition No. 8 6/3

Distance Protection 7SA6
Application

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Application

The distance protection relay 7SA6 is nonswitched incorporating all the additional functions for protection of overhead lines and cables at all voltage levels from 5 to 765 kV.

All methods of neutral point connection (resonant grounding, isolated, solid or low-resistance grounding) are reliably dealt with. The unit can issue single or three-pole TRIP commands as well as CLOSE commands. Consequently both single-pole, three-pole and multiple autoreclosure is possible.

Teleprotection functions as well as ground-fault protection and sensitive ground-fault detection are included. Power swings are detected reliably and non-selective tripping is prevented. The unit operates reliably and selectively even under the most difficult network conditions.

1) Teleprotection schemes can use conventional signaling or serial data exchange

Cost-effective power system management

Fig. 6/2 Function diagram

The SIPROTEC 4 units are numerical relays which also provide control and monitoring functions and therefore support the user in view of a cost-effective power system management. The security and reliability of power supply is increased as a result of minimizing the use of hardware.
The local operation has been designed according to ergonomic criteria. Large, easy-to-read backlit displays are provided.
The SIPROTEC 4 units have a uniform design and a degree of functionality which represents a benchmark-level of performance in protection and control. If the requirements for protection, control or interlocking change, it is possible in the majority of cases to implement such changes by means of parameterization using DIGSI 4 without having to change the hardware.
The use of powerful microcontrollers and the application of digital measured-value conditioning and processing largely suppresses the influence of higher-frequency transients, harmonics and DC components.

ANSI 21/21N FL 50N/51N/67N 50/51/67 50 STUB 68/68T 85/21 27WI 85/67N 50HS 50BF 59/27 81O/U

Protection functions Distance protection Fault locator Directional ground-fault protection Backup overcurrent protection STUB-bus overcurrent stage Power swing detection/tripping Teleprotection for distance protection Weak-infeed protection Teleprotection for ground-fault protection Switch-onto-fault protection Breaker-failure protection Overvoltage/undervoltage protection Over/underfrequency protection

Synchro-check

Auto-reclosure

74TC 86

Trip circuit supervision Lockout (CLOSE command interlocking)

Thermal overload protection

IEE

Sensitive ground-fault detection

6/4 Siemens SIP · Edition No. 8

Distance Protection 7SA6
Construction

Construction

Connection techniques and housing with many advantages
, ½, ²/, and -rack sizes: These are the available housing widths of the 7SA6 relays, referred to a 19" module frame system. This means that previous models can always be replaced. The height is a uniform 245 mm for flush-mounting housings and 266 mm for surface-mounting housings for all housing widths. All cables can be connected with or without ring lugs. Plug-in terminals are available as an option.
It is thus possible to employ prefabricated cable harnesses. In the case of surface mounting on a panel, the connection terminals are located above and below in the form of screw-type terminals. The communication interfaces are located in a sloped case at the top and bottom of the housing. The housing can also be supplied optionally with a detached operator panel (refer to Fig. 6/5), in order to allow optimum operation for all types of applications.

Fig. 6/3 Flush-mounting housing with screw-type terminals

LSP2174-afp.tif LSP2166-afp.tif

Fig. 6/4 Rear view of flush-mounting housing

with covered connection terminals and wirings

LSP2244-afp.eps

Fig. 6/5 Flush-mounting housing with plug-in terminals and detached operator panel

LSP2219-afp.eps LSP2237-afp.tif

Fig. 6/6 Surface-mounting housing with screw-type terminals

Fig. 6/7 Communication interfaces in a sloped case in a surface-mounting housing

14 15

Siemens SIP · Edition No. 8 6/5

Distance Protection 7SA6
Protection functions

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Protection functions

Distance protection (ANSI 21, 21N)
The main function of the 7SA6 is a nonswitched distance protection. By parallel calculation and monitoring of all six impedance loops, a high degree of sensitivity and selectivity is achieved for all types of fault. The shortest tripping time is less than one cycle. All methods of neutral-point connection (resonant grounding, isolated, solid or low-resistance grounding) are reliably dealt with. Single-pole and three-pole tripping is possible. Overhead lines can be equipped with or without series capacitor compensation.
Four pickup methods The following pickup methods can be employed alternatively:
· Overcurrent pickup I>>
· Voltage-dependent overcurrent pickup V/I
· Voltage-dependent and phase angledependent overcurrent pickup V/I/
· Impedance pickup Z<
Load zone The pickup mode with quadrilateral impedance pickup (Z<) is fitted with a variable load zone. In order to guarantee a reliable discrimination between load operation and short-circuit (especially on long high loaded lines), the relay is equipped with a selectable load encroachment characteristic. Impedances within this load encroachment characteristic prevent the distance zones from unwanted tripping.
Absolute phase-selectivity The 7SA6 distance protection incorporates a well-proven, highly sophisticated phase selection algorithm. The pickup of unfaulted phases is reliably eliminated. This phase selection algorithm achieves single-pole tripping and correct distance measurement in a wide application range. Interference to distance measurement caused by parallel lines can be compensated by taking the ground current of the parallel system into account.
This parallel line compensation can be taken into account both for distance measurement and for fault locating.

Fig. 6/8 Impedance fault detection Z< with quadrilateral characteristic

Fig. 6/9 V oltage and angle-dependent overcurrent fault detection V/I/

Fig. 6/10 A ngle pickup for the V/I/ fault detection

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6/6 Siemens SIP · Edition No. 8

Fig. 6/11 Distance zones with circle characteristic

Distance Protection 7SA6
Protection functions

Seven distance zones Six independant distance zones and one separate overreach zone are available. Each distance zone has dedicated time stages, partially separate for single-phase and three-phase faults. Ground faults are detected by monitoring the ground current 3I0 and the zero-sequence voltage 3V0. The quadrilateral tripping characteristic allows use of separate settings for the X and the R directions. Different R settings can be employed for ground and phase faults. This characteristic offers advantages in the case of faults with fault resistance. For applications to medium-voltage cables with low line angles, it may be advantageous to select the distance zones with the optional circle characteristic. All the distance protection zones can be set to forward, reverse or non-directional.

Fig. 6/12 Power swing current and voltage wave forms

LSP2209-afp.tif

Optimum direction detection Use of voltages, which are not involved with the short-circuit loop, and of voltage memories for determination of the fault direction ensure that the results are always reliable.
Elimination of interference signals Digital filters render the unit immune to interference signals contained in the measured values. In particular, the influence of DC components, capacitive voltage transformers and frequency changes is considerably reduced. A special measuring method is employed in order to assure protection selectivity during saturation of the current transformers.
Measuring voltage monitoring Tripping of the distance protection is blocked automatically in the event of failure of the measuring voltage, thus preventing spurious tripping. The measuring voltage is monitored by the integrated fuse failure monitor. Distance protection is blocked if either the fuse failure monitor or the auxiliary contact of the voltage transformer protection switch operates and in this case the EMERGENCY definite-time overcurrent protection can be activated.
Fault locator
The integrated fault locator calculates the fault impedance and the distance-to-fault. The results are displayed in ohms, kilometers (miles) and in percent of the line length. Parallel line compensation and load current compensation for highresistance faults is also available.
Power swing detection (ANSI 68, 68T)
Dynamic transient reactions, for instance short-circuits, load fluctuations, auto-reclosures or switching operations can cause power swings in the transmission network. During power swings, large currents along with small voltages can cause unwanted tripping of distance protection relays. To avoid uncontrolled tripping of the distance protection and to achieve controlled tripping in the event of loss of synchronism, the 7SA6 relay is equipped with an efficient power swing detection function. Power swings can be detected under symmetrical load conditions as well as during single-pole auto-reclosures.

Tele (pilot) protection for distance protection (ANSI 85-21)
A teleprotection function is available for fast clearance of faults up to 100 % of the line length. The following operating modes may be selected:
· POTT
· Directional comparison pickup
· Unblocking
· PUTT acceleration with pickup
· PUTT acceleration with Z1B
· Blocking
· Pilot-wire comparison
· Reverse interlocking
· DUTT, direct underreaching zone transfer trip (together with Direct Transfer Trip function).
The carrier send and receive signals are available as binary inputs and outputs and can be freely assigned to each physical relay input or output. At least one channel is required for each direction.
Common transmission channels are powerline carrier, microwave radio and fiber-optic links. A serial protection data interface for direct connection to a digital communication network or fiber-optic link is available.
7SA6 also permits the transfer of phase-selective signals. This feature is particularly advantageous as it ensures reliable singlepole tripping, if single-pole faults occur on different lines. The transmission methods are suitable also for lines with three ends (three-terminal lines). Phase-selective transmission is also possible with multi-end application, if some user-specific linkages are implemented by way of the integrated CFC logic.
During disturbances in the signaling channel receiver or on the transmission circuit, the teleprotection function can be blocked via a binary input signal without losing the zone selectivity.
The control of the overreach zone Z1B (zone extension) can be switched over to the auto-reclosure function. Transient blocking (current reversal guard) is provided for all the release and blocking methods in order to suppress interference signals during tripping of parallel lines.

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Siemens SIP · Edition No. 8 6/7

Distance Protection 7SA6
Protection functions

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Direct transfer tripping
Under certain conditions on the power system it is necessary to execute remote tripping of the circuit-breaker. The 7SA6 relay is equipped with phase-selective "external trip inputs" that can be assigned to the received inter-trip signal for this purpose.

Weak-infeed protection: echo and/or trip (ANSI 27 WI)
To prevent delayed tripping of permissive schemes during weak or zero infeed situations, an echo function is provided. If no fault detector is picked up at the weak-infeed end of the line, the signal received here is returned as echo to allow accelerated tripping at the strong infeed end of the line. It is also possible to initiate phase-selective tripping at the weak-infeed end. A phaseselective single-pole or three-pole trip is issued if a permissive trip signal (POTT or Unblocking) is received and if the phaseground voltage drops correspondingly. As an option, the weak infeed logic can be equipped according to a French specification.

Overvoltage protection, undervoltage protection (ANSI 59, 27)
A voltage rise can occur on long lines that are operating at noload or that are only lightly loaded. The 7SA6 contains a number of overvoltage measuring elements. Each measuring element is of two-stage design. The following measuring elements are available: · Phase-to-ground overvoltage · Phase-to-phase overvoltage · Zero-sequence overvoltage
The zero-sequence voltage can be connected to the 4th voltage input or be derived from the phase voltages. · Positive-sequence overvoltage of the local end or calculated for the remote end of the line (compounding) · Negative-sequence overvoltage
Tripping by the overvoltage measuring elements can be effected either at the local circuit-breaker or at the remote station by means of a transmitted signal.
The 7SA6 is fitted, in addition, with three two-stage undervoltage measuring elements: · Phase-to-ground undervoltage · Phase-to-phase undervoltage · Positive-sequence undervoltage
The undervoltage measuring elements can be blocked by means of a minimum current criterion and by means of binary inputs.
Frequency protection (ANSI 81O/U)
Frequency protection can be used for overfrequency and underfrequency protection. Unwanted frequency changes in the network can be detected and the load can be removed at a specified frequency setting. Frequency protection can be used over a wide frequency range (45 to 55, 55 to 65 Hz). There are four elements (selectable as overfrequency or underfrequency) and each element can be delayed separately.
Directional ground-fault protection for high-resistance faults (ANSI 50N, 51N, 67N)
In an grounded network it may happen that the distance protection´s sensitivity is not sufficient to detect high-resistance

( ) t =

0, 14
0, 02

I /Ip -1

Fig. 6/13 Normal inverse

ground faults. The 7SA6 protection relay therefore offers protection functions for faults of this nature.
The ground-fault protection can be used with three definite-time stages and one inverse-time stage (IDMT).
Inverse-time characteristics according to IEC 60255-3 and ANSI/IEEE are provided (see "Technical data"). A 4th definite-time stage can be applied instead of the 1st inverse-time stage.
An additional logarithmic inverse-time characteristic is also available.
The direction decision is determined by the ground current and the zero-sequence voltage or by the negative-sequence components V2 and I2. In addition or as an alternative, the direction can be determined with the ground current of an grounded power transformer and the zero-sequence voltage. Dual polarization applications can therefore be fulfilled. Alternatively, the direction can be determined by evaluation of zero-sequence power. Each overcurrent stage can be set in forward or reverse direction or in both directions (non-directional).
The function is equipped with special digital filter algorithms, providing the elimination of higher harmonics. This feature is particularly important for small zero-sequence fault currents which usually have a high content of 3rd and 5th harmonic.
Inrush stabilization and instantaneous switch-onto-fault tripping can be activated separately for each stage as well.
Different operating modes can be selected. The ground-fault protection is suitable for three-phase and, optionally, for singlephase tripping by means of a sophisticated phase selector. It may be blocked during the dead time of single-pole auto-reclose cycles or during pickup of the distance protection.

6/8 Siemens SIP · Edition No. 8

Distance Protection 7SA6
Protection functions

Tele (pilot) protection for directional ground-fault protection (ANSI 85-67N)
The directional ground-fault protection can be combined with the available signaling methods: · Directional comparison · BLOCKING · UNBLOCKING
The transient blocking function (current reversal guard) is also provided in order to suppress interference signals during tripping of parallel lines.
The pilot functions for distance protection and for ground-fault protection can use the same signaling channel or two separate and redundant channels.
Backup overcurrent protection (ANSI 50, 50N, 51, 51N, 67)
The 7SA6 provides a backup overcurrent protection. Two definite-time stages and one inverse-time stage (IDMTL) are available, separately for phase currents and for the ground current. The application can be extended to a directional overcurrent protection (ANSI 67) by taking into account the decision of the available direction detection elements. Two operating modes are selectable. The function can run in parallel to the distance protection or only during failure of the voltage in the VT secondary circuit (emergency operation).
The secondary voltage failure can be detected by the integrated fuse failure monitor or via a binary input from a VT miniature circuit-breaker (VT m.c.b. trip).
Inverse-time characteristics according to IEC 60255-3 and ANSI/ IEEE are provided (see "Technical data").
Instantaneous high-speed switch-onto-fault overcurrent protection (ANSI 50HS)
Instantaneous tripping is required when energizing a faulty line. In the event of large fault currents, the high-speed switch-ontofault overcurrent stage can initiate very fast three-pole tripping.
With smaller fault currents, instantaneous tripping after switchonto-fault is also possible with the overreach distance zone Z1B or with pickup.
The switch-onto-fault initiation can be detected via the binary input "manual close" or automatically via measurement.
Ground-fault detection in systems with a star-point that is not effectively grounded
In systems with an isolated or resonant grounded (grounded) star-point, single-phase ground faults can be detected. The following functions are integrated for this purpose: · Detection of an ground fault by monitoring of the displace-
ment voltage · Determination of the faulted phase by measurement of the
phase-to-ground voltage · Determination of the ground-fault direction by highly accurate
measurement of the active and reactive power components in the residual ground fault current. · Alarm or trip output can be selected in the event of an ground-fault in the forward direction. · Operation measurement of the active and reactive component in the residual ground current during an ground-fault.

Breaker failure protection (ANSI 50BF)
The 7SA6 relay incorporates a two-stage breaker failure protection to detect failures of tripping command execution, for example, due to a defective circuit-breaker. The current detection logic is phase-selective and can therefore also be used in single-pole tripping schemes. If the fault current is not interrupted after a settable time delay has expired, a retrip command or a busbar trip command will be generated. The breaker failure protection can be initiated by all integrated protection functions, as well as by external devices via binary input signals.
STUB bus overcurrent protection (ANSI 50(N)-STUB)
The STUB bus overcurrent protection is a separate definite-time overcurrent stage. It can be activated via a binary input signaling that the line isolator (disconnector) is open.
Separate settings are available for phase and ground faults.
Auto-recIosure (ANSI 79)
The 7SA6 relay is equipped with an auto-reclosure function (AR). The function includes several operating modes: · 3-pole auto-reclosure for all types of faults; different dead
times are available depending on the type of fault · 1-pole auto-reclosure for 1-phase faults, no reclosing for
multi-phase faults · 1-pole auto-reclosure for 1-phase faults and for 2-phase faults
without ground, no reclosing for multi-phase faults · 1-pole auto-reclosure for 1-phase and 3-pole auto-reclosure
for multi-phase faults · 1-pole auto-reclosure for 1-phase faults and 2-phase faults
without ground and 3-pole auto-reclosure for multi-phase faults · Multiple-shot auto-reclosure · Interaction with an external device for auto-reclosure via binary inputs and outputs · Control of the internal AR function by external protection · Interaction with the internal or an external synchro-check · Monitoring of the circuit-breaker auxiliary contacts
In addition to the above-mentioned operating modes, several other operating principles can be employed by means of the integrated programmable logic (CFC).

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Siemens SIP · Edition No. 8 6/9

Distance Protection 7SA6
Protection functions

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Auto-recIosure (continued) (ANSI 79)

Integration of auto-reclosure in the feeder protection allows evaluation of the line-side voltages. A number of voltagedependent supplementary functions are thus available:

Negative active power (-P)

j Q

Positive active

power (+P)

j Q

Inductive (+Q)

· DLC

j A

By means of dead-line check, reclosure is effected only when the line is deenergized (prevention of asynchronous

P j B

breaker closure).

· ADT

LSA_5018a en eps LSA_5019a en eps

The adaptive dead time is employed only if auto-reclosure at the remote sta-

Capacitive (-Q)

tion was successful (reduction of stress

on equipment).

Fig. 6/14 Monitoring of active power

Fig. 6/15 Monitoring of reactive power

· RDT

direction

Reduced dead time is employed in

conjunction with auto-reclosure where no teleprotection

Directional power protection

method is employed: When faults within the zone extension but external to the protected line are switched off for rapid auto-reclosure (RAR), the RDT function decides on the basis of measurement of the return voltage from the remote station which has not tripped whether or not to reduce the dead time.

The 7SA6 has a function for detecting the power direction by measuring the phase angle of the positive-sequence system's power. Fig. 6/15 shows an application example displaying negative active power. An indication is issued in the case when the measured angle (S1) of the positive-sequence system power is

Synchronism check (ANSI 25)
Where two network sections are switched in by control command or following a 3-pole auto-reclosure, it must be ensured that both network sections are mutually synchronous. For this purpose a synchro-check function is provided. After verification of the network synchronism, the function releases the CLOSE command. Alternatively, reclosing can be enabled for different criteria, e.g. checking that the busbar or line is not carrying a

within the P - Q - level sector. This sector is between angles A and B. Via CFC the output signal of the directional monitoring can be linked to the "Direct Transfer Trip (DTT)" function and thus, as reverse power protection, initiate tripping of the CB.
Fig. 6/16 shows another application displaying capacitive reactive power. In the case of overvoltage being detected due to long lines under no-load conditions it is possible to select the lines where capacitive reactive power is measured.

voltage (dead line or dead bus).

Trip circuit supervision (ANSI 74TC)

Fuse failure monitoring and other supervision functions
The 7SA6 relay provides comprehensive supervision functions covering both hardware and software. Furthermore, the measured values are continuously checked for plausibility. Therefore the current and voltage transformers are also included in this supervision system.

One or two binary inputs for each circuit-breaker pole can be used for monitoring the circuit-breaker trip coils including the connecting cables. An alarm signal is issued whenever the circuit is interrupted.
Lockout (ANSI 86)

If any measured voltage is not present due to short-circuit or open circuit in the voltage transformer secondary circuit, the distance protection would respond with an unwanted trip due to this loss of voltage.

Under certain operating conditions it is advisable to block CLOSE commands after a TRIP command of the relay has been issued. Only a manual "RESET" command unblocks the CLOSE command. The 7SA6 is equipped with such an interlocking logic.

This secondary voltage interruption can be detected by means of the integrated fuse failure monitor. Immediate blocking of distance protection and switching to the backup-emergency overcurrent protection is provided for all types of secondary voltage failures.
Additional measurement supervision functions are

Thermal overload protection (ANSI 49)
For thermal protection of cables and transformers an overload protection with an early-warning stage is provided. The thermal replica can be generated with the maximum or mean value of the respective overtemperatures in the three phases, or with the overtemperature corresponding to the maximum phase current.

· Symmetry of voltages and currents · Broken-conductor supervision · Summation of currents and voltages · Phase-sequence supervision.

The tripping time characteristics are exponential functions according to IEC 60255-8 and they take account of heat loss due to the load current and the accompanying drop in temperature of the cooling medium. The previous load is therefore taken into account in the tripping time with overload. A settable alarm stage can output a current or temperature-dependent indication before the tripping point is reached.

6/10 Siemens SIP · Edition No. 8

Distance Protection 7SA6
Protection functions

BCD-coded output of fault location
The fault location calculated by the unit can be output for remote indication in BCD code. The output of the fault location is made in percent of the set line length with 3 decimal digits.

Analog output 0 to 20 mA
Some measured values can be output as analog values (0 to 20 mA). On a plug-in module (Fig. 6/24) two analog channels are made available. Up to two plug-in modules can be installed in the 7SA6. As an option, 2, 4 or no analog channels are available (please refer to the selection and ordering data). The measured values available for output are listed in the technical data.

Commissioning and fault event analyzing
Special attention has been paid to commissioning. All binary inputs and outputs can be displayed and activated directly. This can simplify the wiring check significantly for the user. The operational and fault events and the fault records are clearly arranged. For applications with serial protection data interface, all currents, voltages and phases are available via communication link at each local unit, displayed at the front of the unit with DIGSI 4 or with WEB Monitor. A common time tagging facilitates the comparison of events and fault records.

Fig. 6/16 Web Monitor: Supported commissioning by phasor diagram

WEB Monitor Internet technology simplifies visualization

In addition to the universal DIGSI 4

operating program, the relay contains

a WEB server that can be accessed via a

telecommunication link using a browser

(e.g. Internet Explorer). The advantage of

this solution is to operate the unit with

standard software tools and at the same

time make use of the Intranet/Internet

Fig. 6/17 Web Monitor: Display of the protection direction

infrastructure. Apart from numeric values,

graphical displays in particular provide

clear information and a high degree of operating reliability. Of

course, it is also possible to call up detailed measured value dis-

plays and annunciation buffers. By emulation of the integrated

unit operation on the PC it is also possible to adjust selected

settings for commissioning purposes.

LSP2818.tif

LSP2819.tif

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Siemens SIP · Edition No. 8 6/11

Distance Protection 7SA6
Communication

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Communication

With respect to communication, particular emphasis is placed on the customer requirements in energy automation:
· Every data item is time-stamped at the source, i.e. where it originates.
· Already during the process of communication, information is assigned to the cause thereof (e.g. assignment of the indication "circuit-breaker TRIP" to the corresponding command).
· The communication system automatically handles the transfer of large data blocks (e.g. fault recordings or parameter data files). The user has access to these features without any additional programming effort.
· For the safe execution of a control command the corresponding data telegram is initially acknowledged by the unit which will execute the command. After the release and execution of the command a feedback signal is generated. At every stage of the control command execution particular conditions are checked. If these are not satisfied, command execution may be terminated in a controlled manner.
The units offer a high degree of flexibility by supporting different standards for connection to industrial and power automation systems. By means of the communication modules, on which the protocols run, exchange and retrofit is possible. Therefore, the units will also in future allow for optimal adaptation to changing communication infrastructure such as the application of Ethernet networks which are already widely applied in the power supply sector.

Fig. 6/18 IEC 60870-5-103 star-type RS232 copper conductor connection or fiber-optic connection

Local PC interface
The serial RS232 PC interface accessible from the front of the unit permits quick access to all parameters and fault event data. The use of the DIGSI 4 operating program is particularly advantageous during commissioning.

Service/modem interface
7SA6 units are always fitted with a rear-side hardwired service interface, optionally as RS232 or RS485. In addition to the front-side operator interface, a PC can be connected here either directly or via a modem.
Time synchronization interface
The time synchronization interface is a standard feature in all units. The supported formats are IRIG-B and DCF77.
Reliable bus architecture · RS485 bus
With this data transmission via copper conductors, electromagnetic fault influences are largely eliminated by the use of twisted-pair conductors. Upon failure of a unit, the remaining system continues to operate without any problem.
· Fiber-optic double ring circuit The fiber-optic double ring circuit is immune to electromagnetic interference. Upon failure of a section between two units, the communication system continues to operate without disturbance. It is usually impossible to communicate with a unit that has failed. Should a unit fail, there is no effect on the communication with the rest of the system.

Fig. 6/19 Bus structure for station bus with Ethernet and IEC 61850
Retrofitting: Modules for every type of communication
Communication modules for retrofitting are available for the entire SIPROTEC 4 unit range. These ensure that, where different communication protocols (IEC 61850, IEC 60870-5-103, PROFIBUS, DNP, etc.) are required, such demands can be met. For fiber-optic communication, no external converter is required for SIPROTEC 4.
IEC 61850 protocol
The Ethernet-based IEC 61850 protocol is the worldwide standard for protection and control systems used by power supply corporations. Siemens was the first manufacturer to support this standard. By means of this protocol, information can also be exchanged directly between bay units so as to set up simple masterless systems for bay and system interlocking. Access to the units via the Ethernet but is also possible with DIGSI. It is also possible to retrieve operating and fault records as well as fault recordings via a browser. This Web monitor will also provide a few items of unit-specific information in browser windows.

6/12 Siemens SIP · Edition No. 8

Distance Protection 7SA6
Communication

IEC 60870-5-103 protocol

LSP2162-afpen.tif

IEC 60870-5-103 is an internationally standardized protocol for efficient com-

munication with protection relays.

LSP3.01-0021.tif

IEC 60870-5-103 is supported by a

number of protection device manufacturers and is used worldwide. Supplements

for control functions are defined in

the manufacturer-specific part of this

standard.

PROFIBUS DP

PROFIBUS DP is an industrial communica-

tions standard and is supported by a number of PLC and protection device

Fig. 6/20 820 nm fiber-optic communication Fig. 6/21 Fiber-optic Ethernet communication

module

module for IEC 61850 with integrated Ethernet switch

manufacturers.

DNP 3.0
DNP 3.0 (Distributed Network Protocol, Version 3) is an internationally recognized protection and bay unit communication protocol. SIPROTEC 4 units are Level 1 and Level 2 compatible.

Analog outputs 0 to 20 mA
2 or 4 analog output interfaces for transmission of measured or fault location values are available for the 7SA6. Two analog output interfaces are provided in an analog output module. Up to two analog output modules can be inserted per unit.

Fig. 6/22 RS232/RS485 electrical communication module

LSP2163-afpen.tif LSP2207-afp.tif

Fig. 6/23 Output module 0 to 20 mA,

2 channels

Fig. 6/24 Communication

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Siemens SIP · Edition No. 8 6/13

Distance Protection 7SA6
Communication

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

System solutions for protection and station control
Together with the SICAM power automation system, SIPROTEC 4 can be used with PROFIBUS DP. Over the low-cost electrical RS485 bus, or interference-free via the optical double ring, the units exchange information with the control system. Units equipped with IEC 60870-5-103 interfaces can be connected to SICAM in parallel via the RS485 bus or connected in star by fiber-optic link. Through this interface, the system is open for the connection of units of other manufacturers (see Fig. 6/25).
Because of the standardized interfaces, SIPROTEC units can also be integrated into systems of other manufacturers or in SIMATIC. Electrical RS485 or optical interfaces are available. The optimum physical data transfer medium can be chosen thanks to optoelectrical converters. Thus, the RS485 bus allows low-cost wiring in the cubicles and an interference-free optical connection to the master can be established.
For IEC 61850, an interoperable system solution is offered with SICAM PAS. Via the 100 Mbits/s Ethernet bus, the units are linked with PAS electrically or optically to the station PC. The interface is standardized, thus also enabling direct connection of units of other manufacturers to the Ethernet bus. With IEC 61850, however, the units can also be used in other manufacturers' systems. Units with an IEC 60870-5-103 interface are connected with PAS via the Ethernet station bus by means of serial/Ethernet converters. DIGSI and the Web monitor can also be used via the same station bus.
Serial protection data interface
The tele (pilot) protection schemes can be implemented using digital serial communication. The 7SA6 is capable of remote relay communication via direct links or multiplexed digital communication networks. The serial protection data interface has the following features:
· Fast phase-selective teleprotection signaling for distance protection, optionally with POTT or PUTT schemes
· Signaling for directional ground-fault protection directional comparison for high resistance faults in solidly grounded systems
· Echo-function
· Two and three-terminal line applications can be implemented without additional logic
· Interclose command transfer with the auto-reclosure "Adaptive dead time" (ADT) mode
· 28 remote signals for fast transfer of binary signals
· Flexible utilisation of the communication channels by means of the programmable CFC logic
· Display of the operational measured values of the opposite terminal(s) with phase-angle information relative to a common reference vector
· Clock synchronization: the clock in only one of the relays must be synchronized from an external so called "Absolute Master" when using the serial protection data interface. This relay will then synchronize the clock of the other (or the two other relays in 3 terminal applications) via the protection data interface.
· 7SA522 and 7SA6 can be combined via the protection data interface.

The communication possibilities are identical to those for the line differential protection relays 7SD5 and 7SD610. The following options are available: · FO51), OMA12) module: Optical 820 nm, 2 ST connectors,
FO cable length up to 1.5 km for link to communication networks via communication converters or for direct FO cable connection · FO61), OMA22) module: Optical 820 nm, 2 ST connectors, FO cable length up to 3.5 km, for direct connection via multimode FO cable · FO171): For direct connection up to 24 km3), 1300 nm, for mono-mode fiber 9/125 m, LC-Duplex connector · FO181): For direct connection up to 60 km3) 1300 nm, for mono-mode fiber 9/125 m, LC-Duplex connector · FO191): For direct connection up to 100 km3) 1550 nm, for mono-mode fiber 9/125 m, LC-Duplex connector · FO301): For transmission with the IEEE C37.94 standard.
The link to a multiplexed communication network is made by separate communication converters (7XV5662). These have a fiber-optic interface with 820 nm and ST connectors to the protection relay. The link to the communication network is optionally an electrical X21 or a G703.1 interface. If the connection to the multiplexor supports IEEE C37.94, a direct fibre optic connection to the relay is possible using the FO30 module.
For operation via copper wire communication (pilot wires), a modern communication converter for copper cables is available. This operates with both the two-wire and three-wire copper connections which were used by conventional differential protection systems before. The communication converter for copper cables is designed for 5 kV insulation voltage. An additional 20 kV isolation transformer can extend the field of applications of this technique into ranges with higher insulation voltage requirements. With SIPROTEC 4 and the communication converter for copper cables a digital follow-up technique is available for two-wire protection systems (typical 15 km) and all three-wire protection systems using existing copper communication links.
Communication data: · Supported network interfaces G703.1 with 64 kBit/s;
X21/RS422 with 64 or 128 or 512 kBit/s; IEEE C37.94 · Max. channel delay time 0.1 ms to 30 ms (in steps of 0.1 ms) · Protocol HDLC · 32-bit CRC-check according to CCITT and ITU · Each protection relay possesses a unique relay address · Continuous communication link supervision: Individual faulty
data telegrams do not constitute an immediate danger, if they occur only sporadically. The statistical availability, per minute and hour, of the serial protection data interface can be displayed.
Figure 6/26 shows four applications for the serial protection data interface on a two-terminal line.
1) For flush-mounting housing. 2) For surface-mounting housing. 3) For surface-mounting housing the internal fiber-optic module
OMA1 will be delivered together with an external repeater.

6/14 Siemens SIP · Edition No. 8

Distance Protection 7SA6
Communication

Fig. 6/25 Communication topologies for the serial protection data interface on a two-terminal line

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 6/15

Distance Protection 7SA6
Communication

Three-terminal lines can also be protected

with a tele (pilot) protection scheme by using SIPROTEC 4 distance protection

relays. The communication topology may

then be a ring or a chain topology, see

Fig. 6/27. In a ring topology a loss of one

data connection is tolerated by the system. The topology is re-routed to become a

chain topology within less than 100 ms. To

reduce communication links and to save

money for communications, a chain topology may be generally applied.

Ring topology

10 11

Chain topology Fig. 6/26 Ring or chain communication topology

15
6/16 Siemens SIP · Edition No. 8

Typical connection
Connection of current and voltage transformers
3 phase current transformers with neutral point in the line direction, I4 connected as summation current transformer (= 3I0): Holmgreen circuit
3 voltage transformers, without connection of the broken (open) delta winding on the line side; the 3V0 voltage is derived internally.

Distance Protection 7SA6
Typical connection
1 2 3 4

Fig. 6/27 Example of connection for current and voltage transformers
Alternative current measurement
The 3 phase current transformers are connected in the usual manner. The neutral point is in line direction. I4 is connected to a separate neutral core-balance CT, thus permitting a high sensitive 3I0 measurement.
Note: Terminal Q7 of the I4 transformer must be connected to the terminal of the core balance CT pointing in the same direction as the neutral point of the phase current transformers (in this case in line direction). The voltage connection is effected in accordance with Fig. 6/28, 6/32 or 6/33.
Fig. 6/28 Alternative connection of current transformers for sensitive ground-current measuring with core-balance current transformers

5 6 7 8 9 10

15
Siemens SIP · Edition No. 8 6/17

Distance Protection 7SA6
Typical connection

Alternative current connection

3 phase current transformers with neutral point in the line direction, I4 connected to

a current transformer in the neutral point

of an grounded transformer for directional

ground-fault protection. The voltage connection is effected in accordance with

Fig. 6/28, 6/32 or 6/33.

Alternative current connection

3 phase current transformers with neutral

point in the line direction, I4 connected to

summation current of the parallel line for

parallel line compensation on overhead

lines. The voltage connection is effected in accordance with Fig. 6/28, 6/32 or 6/33.

Fig. 6/29 Alternative connection of current transformers for measuring neutral current of an grounded power transformer

Fig. 6/30 Alternative connection of current transformers for measuring the ground current of a parallel line

15
6/18 Siemens SIP · Edition No. 8

Alternative voltage connection
3 phase voltage transformers, V4 connected to broken (open) delta winding (Ven) for additional summation voltage monitoring and ground-fault directional protection. The current connection is effected in accordance with Fig. 6/28, 6/29, 6/30 and 6/31.

Distance Protection 7SA6
Typical connection
1 2 3

Fig. 6/31 Alternative connection of voltage transformers for measuring the displacement voltage (e-n voltage)

Alternative voltage connection

3 phase voltage transformers, V4 con-

nected to busbar voltage transformer for

synchro-check. Note: Any phase-to-phase or phase-to-

ground voltage may be employed as the

busbar voltage. Parameterization is carried

out on the unit. The current connection is effected in accordance with Fig. 6/28, 6/29,

6/30 and 6/31.

Fig. 6/32 Alternative connection of voltage transformers for measuring the busbar voltage

10 11

15
Siemens SIP · Edition No. 8 6/19

Distance Protection 7SA6
Technical data

1 2 3 4 5 6 7 8 9 10 11 12 13

General unit data

Analog inputs

Rated frequency

50 or 60 Hz (selectable)

Rated current Inom
Rated voltage Vnom
Power consumption With Inom = 1 A With Inom = 5 A For IE, sensitive with 1 A Voltage inputs

1 or 5 A (selectable) 80 to 125 V (selectable)
Approx. 0.05 VA Approx. 0.30 VA Approx. 0.05 VA 0.10 VA

Overload capacity of current circuit (r.m.s.)
Thermal
Dynamic (peak value)

500 A for 1 s 150 A for 10 s 20 A continuous 1250 A (half cycle)

Ground current Sensitive
Dynamic (peak value)

300 A for 1 s 100 A for 10 s 15 A continuous 750 A (half cycle)

Thermal overload capacity of voltage circuit

230 V continuous

Auxiliary voltage

Rated voltages

DC 24 to 48 V DC 60 to 125 V DC 110 to 250 V and AC 115 to 230 V (50/60 Hz)

Permissible tolerance

-20 % to +20 %

Superimposed AC voltage (peak-to-peak)

15 %

Power consumption Quiescent Energized

Approx. 5 W Approx. 12 W to 18 W, depending on design

Bridging time during failure of the auxiliary voltage
For Vaux = 48 V and Vaux 110 V 50 ms For Vaux = 24 V and Vaux = 60 V 20 ms

Binary inputs

Quantity 7SA610*-*A/E/J 7SA610*-*B/F/K 7SA6*1*-*A/E/J 7SA6*1*-*B/F/K 7SA6*2*-*A/E/J 7SA6*2*-*B/F/K 7SA6*2*-*C/G/L
Rated voltage range Pickup threshold

5 7 13 20 21 29 33 24 to 250 V, bipolar DC 17 or 73 or 154 V, bipolar

Functions are freely assignable 1

Pickup/reset voltage thresholds DC 9 V/ DC 10 V or DC 88 V/ DC 44 V, Ranges are settable by means of or DC 176 V/ DC 88 V bipolar jumpers for each binary input (3 nominal ranges DC 17/73/154 V)

Maximum permissible voltage DC 300 V

Current consumption, energized Approx. 1.8 mA

Input impulse suppression

220 nF coupling capacitance at 220 V with a recovery time >60 ms

Output contacts

"Unit ready" contact (live status contact)

1 NC/NO contact1)

Command/indication relay

Quantity 7SA610*-*A/E/J 7SA610*-*B/F/K 7SA6*1*-*A/E/J 7SA6*1*-*B/F/K 7SA6*2*-*A/E/J 7SA6*2*-*B/F/K 7SA6*2*-*C/G/L

5 NO contacts, 3 NC/NO contact1)
5 NO contacts, 12 NO contacts, 4 NC/NO contacts1)
8 NO contacts, 4 power relays2) 19 NO contacts, 5 NC/NO contacts1) 26 NO contacts, 6 NC/NO contacts1) 11 NO contacts, 8 power relays2)

NO/NC contact

Switching capacity Make Break, high-speed trip outputs Break, contacts
Break, contacts (for resistive load) Break, contacts (for = L/R 50 ms)

1000 W / VA 1000 W / VA 30 VA 40 W
25 VA

Switching voltage

250 V

Permissible total current

30 A for 0.5 seconds 5 A continuous

Operating time, approx. NO contact NO/NC contact (selectable) Fast NO contact High-speed NO trip outputs

8 ms 8 ms 5 ms < 1 ms

Power relay for direct control of disconnector actuator motors

Switching capacity Make for 48 to 250 V Break for 48 to 250 V Make for 24 V Break for 24 V

1000 W/ VA 1000 W/ VA 500 W/ VA 500 W/ VA

Switching voltage

250 V

Permissible total current

30 A for 0.5 seconds 5 A continuous

Max. operating time

30 s

Permissible relative operating 1 % time

LEDs

RUN (green) ERROR (red) LED (red), function can be assigned 7SA610 7SA6*1/2/3

Quantity 1 1
7 14

15
6/20 Siemens SIP · Edition No. 8

1) Can be set via jumpers.
2) Each pair of power relays is mechanically interlocked to prevent simultaneous closing.

Distance Protection 7SA6
Technical data

Unit design Housing Dimensions

Degree of protection acc. to EN 60529
Surface-mounting housing Flush-mounting housing Front Rear For the terminals

Weight

Flush-mounting 1/3 x 19"

housing

1/2 x 19"

2/3 x 19"

1/1 x 19"

Surface-mounting 1/3 x 19"

housing

1/2 x 19"

1/1 x 19"

7XP20 Refer to part 14 for dimension drawings
IP 51
IP 51 IP 50 IP 20 with terminal cover put on
4 kg 6 kg 8 kg 10 kg 6 kg 11 kg 19 kg

Electrical tests

Specifications

Standards

IEC 60255 (product standards) IEEE Std C37.90.0/.1/.2; UL 508 VDE 0435 Further standards see "Individual functions"

Insulation tests

Standards

IEC 602555 and 60870-2-1

High-voltage test (routine test)

All circuits except for power supply, binary inputs, high-speed outputs, communication and time synchronization interfaces

2.5 kV (r.m.s.), 50 Hz

Auxiliary voltage, binary

DC 3.5 kV

inputs and high-speed outputs

(routine test)

only isolated communication interfaces and time synchroni-
zation interface (routine test)

500 V (r.m.s.), 50 Hz

Impulse voltage test (type test) 5 kV (peak); 1.2/50 µs; 0.5 Ws,

All circuits except for communi- 3 positive and 3 negative impulses in

cation interfaces and time

intervals of 5 s

synchronization interface,

class III

EMC tests for noise immunity; type tests

Standards

IEC 60255-6/-22 (product standard) EN 61000-6-2 (generic standard), VDE 0435 part 301 DIN VDE 0435-110

High-frequency test

2.5 kV (peak); 1 MHz; = 15 ms;

IEC 60255-22-1 class III and

400 surges per s; test duration 2 s,

VDE 0435 Section 303, class III Ri = 200

Electrostatic discharge

8 kV contact discharge; 15 kV air

IEC 60255-22-2 class IV

discharge; both polarities; 150 pF;

and IEC 61000-4-2, class IV

Ri = 330

Irradiation with HF field, frequency 10 V/m; 80 to 1000 MHz: 80 % AM;

sweep

1 kHz

IEC 60255-22-3 (report) class III 10 V/m; 800 to 960 MHz: 80 % AM;

1 kHz

IEC 61000-4-3, class III

10 V/m; 1.4 to 2 GHz: 80 % AM; 1 kHz

Irradiation with HF field, single 10 V/m; 80, 160, 450, 900 MHz;

frequencies

80 % AM; 1 kHz; duty cycle > 10 s

IEC 60255-22-31, IEC 61000-4-3, 900 MHz; 50 % PM, repetition

class III

frequency 200 Hz

amplitude/pulse modulated

Fast transient disturbance/bursts 4 kV; 5/50 ns; 5 kHz;

IEC 60255-22-4 and

burst length = 15 ms;

IEC 61000-4-4, class IV

repetition rate 300 ms; both polari-

ties; Ri = 50 ; test duration 1 min

High-energy surge voltages

Impulse: 1.2/50 µs

(SURGE),

IEC 61000-4-5 installation class III

Auxiliary supply

Common mode: 2 kV; 12 ; 9 µF

Differential mode:1 kV; 2 ; 18 µF

Analog measurement inputs, binary inputs, relays output

Common mode: 2 kV; 42 ; 0.5 µF Differential mode: 1 kV; 42 ; 0.5 µF

Line-conducted HF, amplitudemodulated, IEC 61000-4-6, class III

10 V; 150 kHz to 80 MHz; 80 % AM; 1 kHz

Power system frequency magnetic 30 A/m continuous; 300 A/m for 3 s;

field

IEC 61000-4-8, class IV;

50 Hz

IEC 60255-6

0.5 mT; 50 Hz

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 6/21

Distance Protection 7SA6
Technical data

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Oscillatory surge withstand capability, IEEE Std C37.90.1
Fast transient surge withstand capability, IEEE Std C37.90.1
Radiated electromagnetic interference IEEE Std C37.90.2

2.5 kV (peak); 1 MHz = 50 s; 400 surges per second, test duration 2 s, Ri = 200
4 kV; 5/50 ns; 5 kHz; burst length = 15 ms repetition rate 300 ms, ; both polarities; test duration 1 min; Ri = 50
35 V/m; 25 to 1000 MHz, amplitude and pulse-modulated

Damped oscillations IEC 60694, IEC 61000-4-12

2.5 kV (peak value); polarity alternating 100 kHz; 1 MHz; 10 and 50 MHz; Ri = 200

EMC tests for noise emission; type test

Standard

EN 61000-6-3 (generic standard)

Radio noise voltage to lines, only 150 kHz to 30 MHz

auxiliary voltage

Limit class B

IEC-CISPR 22

Radio interference field strength 30 to 1000 MHz

IEC-CISPR 22

Limit class B

Harmonic currents on the network lead at AC 230 V, IEC 61000-3-2

Class A limits are observed

Voltage fluctuations and flicker Limits are observed on the network incoming feeder at AC 230 V, IEC 61000-3-3

Climatic stress tests

Standard

IEC 60255-6

Temperatures

Type-tested acc. to IEC 60068-2-1 -25 °C to +85 °C / -13 °F to +185 °F and -2, test Bd

Temporarily permissible operating -20 °C to +70 °C / -4 °F to +158 °F temperature, tested for 96 h (Legibility of display may be impaired above +55 °C / +131 °F)

Recommended permanent operating temperature acc. to IEC 60255-6

-5 °C to +55 °C / +23 °F to +131 °F

L imiting temperature during -25 °C to +55 °C / -13 °F to 131 °F permanent storage

L imiting temperature during -25 °C to +70 °C / -13 °F to +158 °F transport

Humidity

Permissible humidity stress:

Annual average on 75 % relative

It is recommended to arrange the humidity; on 56 days per year up to

units in such a way that they are 93 % relative humidity; condensation

not exposed to direct sunlight or is not permitted.

pronounced temperature changes

that could cause condensation.

Mechanical stress test

Vibration, shock stress and seismic vibration

During operation

Standards

IEC 60255-21 and IEC 60068-2

Vibration IEC 60255-21-1, class 2 IEC 60068-2-6

Sinusoidal 10 to 60 Hz: ± 0.075 mm amplitude; 60 to 150 Hz: 1 g acceleration frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes

Shock IEC 60255-21-2, class 1 IEC 60068-2-27

Semi-sinusoidal Acceleration 5 g, duration 11 ms, 3 shocks on each of the 3 axes in both directions

Seismic vibration IEC 60255-21-2, class 1 IEC 60068-3-3

During transport

Standards

IEC 60255-21 and IEC 60068-2

Vibration IEC 60255-21-1, class 2 IEC 60068-2-6

Sinusoidal 5 to 8 Hz: ± 7.5 mm amplitude; 8 to 150 Hz: 2 g acceleration Frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes

Shock IEC 60255-21-2, class 1 IEC 60068-2-27

Semi-sinusoidal Acceleration 15 g, duration 11 ms, 3 shocks on each of the 3 axes in both directions

Continuous shock IEC 60255-21-2, class 1 IEC 60068-2-29

Semi-sinusoidal Acceleration 10 g, duration 16 ms, 1000 shocks on each of the 3 axes in both directions

Futher information can be found in the current manual at: www.siemens.com/siprotec

6/22 Siemens SIP · Edition No. 8

Distance Protection 7SA6
Selection and ordering data

Operator panel with: 4-line backlit display, function keys, numerical keys, PC interface
1) Rated current can be selected by means of jumpers.
2) T ransition between the two auxiliary voltage ranges can be selected by means of jumpers.
3) T he binary input thresholds are selectable in three stages by means of jumpers, exception: versions with power relays have some binary inputs with only two binary input thresholds.
4) F ast relays are identified in the terminal connection diagram.
5) Power relay for direct control of disconnector actuator motors. Each pair of contacts is mechanically interlocked to prevent simultaneous closure.

Description 7SA61 distance protection relay for all voltage levels
Housing, number of LEDs Housing width 19", 7 LEDs Housing width ½ 19", 14 LEDs Housing width 19", 14 LEDs Housing width ²/ 19", 14 LEDs

Order No. 7SA61 - -

see pages 6/32

to 6/35

Measuring inputs (4 x V/4 x I)

Iph = 1 A1), Ie = 1 A1) (min. = 0.05 A)

Iph = 1 A1), Ie = sensitive (min. = 0.003 A)

Iph = 5 A1), Ie = 5 A (min. = 0.25 A)

Iph = 5 A1), Ie = sensitive (min. = 0.003 A)

Rated auxiliary voltage (power supply, binary inputs)

DC 24 to 48 V, binary input threshold 17 V3)

DC 60 to 125 V 2), binary input threshold 17 V3)

DC 110 to 250 V 2), AC 115 to 230 V, binary input threshold 73 V3)

Binary/ Indication/ Fast High- Power

indication command relay4) speed relay5)

inputs outputs

trip

incl.

output

live status

contact

Flush-

mounting mounting

housing/ housing/

screw-type plug-in

terminals terminals

Surfacemounting housing/ screw-type terminals

For 7SA610

For 7SA611

For 7SA612

For 7SA613

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Siemens SIP · Edition No. 8 6/23

Distance Protection 7SA6
Selection and ordering data

Operator panel with:

backlit graphic display for

single-line diagram

control keys,

key-operated switches, function keys,

numerical keys,

PC interface

LSA2539-agpen.eps

Description 7SA63 distance protection relay for all voltage levels
Housing, number of LEDs Housing width ½ 19", 14 LEDs Housing width 19", 14 LEDs
Measuring inputs (4 x V/4 x I) Iph = 1 A1), Ie = 1 A1) (min. = 0.05 A) Iph = 1 A1), Ie = sensitive (min. = 0.003 A) Iph = 5 A1), Ie = 5 A (min. = 0.25 A) Iph = 5 A1), Ie = sensitive (min. = 0.003 A)
Rated auxiliary voltage (power supply, binary inputs) DC 24 to 48 V, binary input threshold 17 V3) DC 60 to 125 V 2), binary input threshold 17 V3) DC 110 to 250 V 2), AC 115 to 230 V, binary input threshold 73 V3)

Order No. 7SA63 - -
1 2
see pages 6/32 to 6/35 1 2 5 6
2 4 5

Binary/ Indication/ Fast High- Power

indication command relay4) speed relay5)

inputs outputs

trip

incl.

output

live status

contact

Flush-

mounting mounting

housing/ housing/

screw-type plug-in

terminals terminals

Surfacemounting housing/ screw-type terminals

For 7SA631

For 7SA632

14 15

1) Rated current can be selected by means of jumpers.
2) T ransition between the two auxiliary voltage ranges can be selected by means of jumpers.
3) T he binary input thresholds are selectable in three stages by means of jumpers, exception: versions with power relays have some binary inputs with only two binary input thresholds.

4) F ast relays are identified in the terminal connection diagram.
5) P ower relay for direct control of disconnector actuator motors. Each pair of contacts is mechanically interlocked to prevent simultaneous closure.

6/24 Siemens SIP · Edition No. 8

Units with detached operator panel with: backlit graphic display control keys, key-operated switches, function keys, numerical keys, PC interface

LSA2540-agpen.eps

Distance Protection 7SA6
Selection and ordering data

Description 7SA64 distance protection relay for all voltage levels

Housing, number of LEDs Housing width ½ 19", 14 LEDs Housing width 19", 14 LEDs

Measuring inputs (4 x V/4 x I) Iph = 1 A1), Ie = 1 A1) (min. = 0.05 A) Iph = 1 A1), Ie = sensitive (min. = 0.003 A) Iph = 5 A1), Ie = 5 A (min. = 0.25 A) Iph = 5 A1), Ie = sensitive (min. = 0.003 A)

Rated auxiliary voltage (power supply, binary inputs) DC 24 to 48 V, binary input threshold 17 V3) DC 60 to 125 V 2), binary input threshold 17 V3) DC 110 to 250 V 2), AC 115 to 230 V, binary input threshold 73 V3)

Binary/ Indication/ Fast High- Power Flush-

Flush-

indication command relay4) speed relay5) mounting mounting

inputs outputs

trip

housing/ housing/

incl.

output

screw-type plug-in

live status

terminals terminals

contact

For 7SA641

For 7SA642

Order No.

7SA64 - -

see pages 6/32 to 6/35

2 4

P B

A J

B K N

14 15

Siemens SIP · Edition No. 8 6/25

Distance Protection 7SA6
Selection and ordering data

Description

7SA6 distance protection relay for all voltage levels

Region-specific default settings / language settings 1)

Region DE, language: German

Region World, language: English (GB) Region US, language: English (US)

Region FR, French

Region World, Spanish

Region World, Italian Region World, language: Russian

Region World, language: Polish

Port B

Empty

System interface, IEC 60870-5-103 protocol, electrical RS232

System interface, IEC 60870-5-103 protocol, electrical RS485

System interface, IEC 60870-5-103 protocol, optical 820 nm, ST connector

2 analog outputs, each 0.....20 mA

System interface, PROFIBUS DP, electrical RS485

System interface, PROFIBUS DP, optical 820 nm, double ring 2), ST connector

System interface, DNP 3.0, electrical RS485 System interface, DNP 3.0, optical 820 nm, ST connector2)

System interface, IEC 61850, 100 Mbit/s Ethernet, electrical, duplicate, RJ45 plug connectors

System interface, IEC 61850, 100 Mbit/s Ethernet, optical, double, LC connector3)

Order No.

Order code

7SA6 - -

see pages A 6/33 to 6/35 B C D E F G H

L 0A

L 0B

L 0G

L 0H

L 0R

L 0S

10 11 12 13 14

1) Definitions for region-specific default settings and functions:
Region DE: preset to f = 50 Hz and line length in km, only IEC inverse characteristic can be selected, directional earth (ground) fault protection: no logarithmic inverse characteristic, no direction decision with zero-sequence power Sr; distance protection can be selected with quadrilateral or circle characteristic.
Region US: preset to f = 60 Hz and line length in miles, ANSI inverse characteristic only, directional earth (ground) fault protection: no logarithmic inverse characteristic, no direction decision with zero-sequence power Sr, no U0 inverse characteristic.
Region World:preset to f = 50 Hz and line length in km, directional earth (ground) fault protection: no direction decision with zero-sequence power Sr, no U0 inverse characteristic.
Region FR:preset to f = 50 Hz and line length in km, directional earth (ground) fault protection: no U0 inverse characteristic, no logarithmic inverse characteristic, weak infeed logic selectable between French specification and world specification.
2) Optical double ring interfaces are not available with surface mounting housings.
3)F or surface mounting housing applications please order the relay with electrical Ethernet interface and use a separate fiber-optic switch.

15
6/26 Siemens SIP · Edition No. 8

Distance Protection 7SA6
Selection and ordering data

Description
7SA6 distance protection relay for all voltage levels
Port C and port D Port C: DIGSI/modem, electrical RS232, Port D: empty Port C: DIGSI/modem, electrical RS485, Port D: empty Port C and Port D installed
Port C DIGSI/modem, electrical RS232 DIGSI/modem, electrical RS485
Port D Protection data interface: optical 820 nm, two ST connectors, FO cable length up to 1.5 km For direct connection via multi-mode FO cable or communication networks 1) Protection data interface: optical 820 nm, two ST connectors, FO cable length up to 3.5 km For direct connection via multi-mode FO cable Two analog outputs, each 0...20 mA Protection data interface: optical 1300 nm, LC-Duplex connector FO cable length up to 24 km for direct connection via mono-mode FO cable2) Protection data interface: optical 1300 nm, LC-Duplex connector FO cable length up to 60 km for direct connection via mono-mode FO cable2)3) Protection data interface: optical 1550 nm, LC-Duplex connector FO cable length up to 100 km for direct connection via mono-mode FO cable2)4) FO30 optical 820 nm, 2-ST-connector, length of optical fibre up to 1.5 km for multimode fibre, for communication networks with IEEEC37.94 interface or direct optical fibre connection (not available for surface-mounted housing)

Order No.

Order code

7SA6 - -

see pages

6/34 and

1 6/35

3
1 2

4
A

B K

G
H6
J

1)F or suitable communication converters 7XV5662 (optical to G703.1/X21/RS422 or optical to pilot wire) see "Accessories".
2)F or surface-mounting housing applications an internal fiber-optic module 820 nm will be delivered in combination with an external repeater.
3)F or distances less than 25 km, two optical attenuators 7XV5107-0AA00 are required to avoid optical saturation of the receiver element.
4)F or distances less than 50 km, two optical attenuators 7XV5107-0AA00 are required to avoid optical saturation of the receiver element.

13 14 15
Siemens SIP · Edition No. 8 6/27

Distance Protection 7SA6
Selection and ordering data

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Description 7SA6 distance protection relay for all voltage levels

Functions 1 Trip mode
3-pole 3-pole 3-pole 3-pole 1/3-pole 1/3-pole 1/3-pole 1/3-pole

Thermal overload

BCD-coded output for

protection (ANSI 49) fault location

Functions 2
Distance protection pickup (ANSI 21, 21N)
I> V Quadrilateral (Z<) Quadrilateral (Z<), V / Quadrilateral (Z<) Quadrilateral (Z<), V / V Quadrilateral (Z<) Quadrilateral (Z<), V / Quadrilateral (Z<) Quadrilateral (Z<), V /

Power swing detection (ANSI 68, 68T)

Functions 3
Auto-reclosure (ANSI 79)

Synchro-check (ANSI 25)

Breaker failure protection (ANSI 50BF)

Parallel line compensation
1) 1) 1) 1) 1)
Over/undervoltage protection V>, V< (ANSI 27, 59) Over/underfrequency protection (ANSI 81)

Functions 4
Directional ground-fault Ground-fault detection Measured values protection, grounded compensated/ isolated extended Min, max, mean networks (ANSI 50N, networks 51N, 67N)

Order No. 7SA6 - -
0 1 2 3 4 5 6 7
A B C D F G J K L N P
A B C D E F G H J K L M N P Q R
0 1 2 3 4 5 6 7

1) Only with position 7 of Order No. = 1 or 5. 2) Only with position 7 of Order No. = 2 or 6.

6/28 Siemens SIP · Edition No. 8

Description 7SA6 distance protection relay for all voltage levels
Preferential types Functions 1

Distance Protection 7SA6
Selection and ordering data

Order No.

7SA6 - -

Trip mode, 3-pole Trip mode 1 or 3-pole Pickup I> Pickup V Z< (quadrilateral) V/ Power swing detection Parallel line compensation Auto-reclosure Synchro-check Breaker failure protection Voltage protection Frequency protection Ground-fault protection directional for grounded networks Ground-fault directional for compensated isolated networks Overload protection Measured values, extended, min. max. mean

Basic version

Medium voltage, cables

Medium voltage, overhead lines

High voltage, cables

High voltage, overhead lines

1 AB 0

1 AB 1

3 BD6

1 BD7

3 BM6

3 BM7

3 GH4 3 GH5
7 P R 4 7 P R 5

8 9 10

1) Only with position 7 of Order No. = 2 or 6. 2) Only with position 7 of Order No. = 1 or 5.

15
Siemens SIP · Edition No. 8 6/29

Distance Protection 7SA6
Selection and ordering data

Accessories
1 2 3 4

Description

Order No.

Connecting cable (copper) Cable between PC/notebook (9-pin connector) and protection unit (9-pin connector) (contained in DIGSI 4, but can be ordered additionally)
Voltage transformer miniature circuit-breaker Rated current 1.6 A; thermal overload release 1.6 A; overcurrent trip 6 A
Manual for 7SA6 English, V4.70 and higher
German, V4.70

7XV5100-4
3RV1611-1AG14 C53000-G1176-C156-7 C53000-G1100-C156-8

15
6/30 Siemens SIP · Edition No. 8

Accessories

Distance Protection 7SA6
Selection and ordering data

Description
Opto-electric communication converters Optical to X21/RS422 or G703.1 Optical to pilot wires

Order No.
1
7XV5662-0AA00 7XV5662-0AC00

Additional interface modules Protection data interface FO5, OMA1, 820 nm, multi-mode FO cable,

ST connector, 1.5 km

C53207-A351-D651-1

Protection data interface FO6, OMA2, 820 nm, multi-mode FO cable,

ST connector, 3.5 km Protection data interface FO17, 1300 nm, mono-mode FO cable,

C53207-A351-D652-1

LC-Duplex connector, 24 km

C53207-A351-D655-1

Protection data interface FO18, 1300 nm, mono-mode FO cable,

LC-Duplex connector, 60 km

C53207-A351-D656-1

Protection data interface FO19, 1550 nm, mono-mode FO cable,

LC-Duplex connector, 100 km

C53207-A351-D657-1

Optical repeaters

Serial repeater (2-channel), opt. 1300 nm, mono-mode FO cable, LC-Duplex connector, 24 km

7XV5461-0BG00

Serial repeater (2-channel), opt. 1300 nm, mono-mode FO cable, LC-Duplex connector, 60 km

7XV5461-0BH00

Serial repeater (2-channel), opt. 1550 nm, mono-mode FO cable,

LC-Duplex connector, 100 km

7XV5461-0BJ00

LSP2289-afp.eps

Accessories
Fig. 6/33 Mounting rail for 19" rack

LSP2091-afp.eps

LSP2090-afp.eps

Fig. 6/34 2-pin connector

Fig. 6/35 3-pin connector

LSP2092-afp.eps

LSP2093-afp.eps

Fig. 6/36 Short-circuit link for current contacts

Fig. 6/37 Short-circuit link for voltage contacts/ indications contacts

Description

Order No.

Connector

2-pin 3-pin

C73334-A1-C35-1 C73334-A1-C36-1

Crimp connector
Crimping tool

CI2 0.5 to 1 mm2

0-827039-1 0-827396-1

CI2 0.5 to 2.5 mm2

0-827040-1 0-827397-1

Type III+ 0.75 to 1.5 mm2 0-163083-7 0-163084-2

For type III+ and matching female For CI2 and matching female

0-539635-1 0-539668-2 0-734372-1 1-734387-1

19"-mounting rail

C73165-A63-D200-1

Short-circuit For current terminals

links

For other terminals

C73334-A1-C33-1 C73334-A1-C34-1

Safety cover large for terminals small

C73334-A1-C31-1 C73334-A1-C32-1

Size of Supplier Fig. package

Siemens 6/35

Siemens 6/36

4000

Siemens 6/34

Siemens 6/37

Siemens 6/38

Siemens 6/4

1) Your local Siemens representative can inform you on local suppliers.

9 10 11 12 13 14 15

Siemens SIP · Edition No. 8.1 6/31

Distance Protection 7SA6
Connection diagram

LSA2532-agpen.eps

7
Fig. 6/38 Connection diagram
8

14 15

1) Starting from unit version ..../EE. Fig. 6/39 Serial interfaces

6/32 Siemens SIP · Edition No. 8

LSA2532-agpen.eps

Note: For serial interfaces see Fig. 6/40. Fig. 6/40 Connection diagram

Distance Protection 7SA6
Connection diagram
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 6/33

Distance Protection 7SA6
Connection diagram

SA2545-agpen.eps

13 14

1) Starting from unit version .../EE. 2) High-speed trip outputs in versions 7SA6*1*-*M, 7SA*1*-*N, 7SA*1*-*P.
Time advantage of high-speed relays over fast relays: approx. 5 ms 3) Time advantage with fast relay approx. 3 ms. 4) Version with 3-pole tripping. 5) Version with 1/3-pole tripping. Note: For serial interfaces see Fig. 6/40.

Fig. 6/41 Connection diagram

6/34 Siemens SIP · Edition No. 8

Distance Protection 7SA6
Connection diagram

SA2545-agpen.eps

1) Version with 3-pole tripping. 2) Each pair of contacts is mechanically interlocked to prevent simultaneous closure. 3) Version with 1/3-pole tripping. Note: For serial interfaces see Fig. 6/40.
Fig. 6/42 Connection diagram

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 6/35

Distance Protection 7SA6
Connection diagram

SA2546-agpen.eps

14 15

1) 7SA613 is only available in a 2/3 x 19" flush-mounting housing. 2) Starting from unit version .../EE 3) Time advantage with fast relay approx. 3 ms. 4) High-speed trip outputs in versions 7SA6*2*-*M, 7SA6*2*-*P,
7SA6*2*-*R. Time advantage of high-speed relays over fast relays: approx. 5 ms
Fig. 6/43 Connection diagram

6/36 Siemens SIP · Edition No. 8

5) V ersion with 3-pole tripping. 6) Version with 1/3-pole tripping. Note: For serial interfaces see Fig. 6/40.

SA2546-agpen.eps
1) Starting from unit version .../EE.
2) High-speed trip outputs in versions 7SA6*2*-*N, 7SA6*2*-*Q, 7SA6*2*-*S.
3) Time advantage with fast relay approx. 3 ms.
4) Version with 3-pole tripping.
5) Version with 1/3-pole tripping. Time advantage of highspeed relays over fast relays: approx. 5 ms.
Note: For serial interfaces see Fig. 6/40. Fig. 6/44 Connection diagram

Distance Protection 7SA6
Connection diagram
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 6/37

Distance Protection 7SA6
Connection diagram

SA2546-agpen.eps

13 14 15

1) Version with 3-pole tripping.
2) Each pair of contacts is mechanically interlocked to prevent simultaneous closure.
3) Version with 1/3-pole tripping.
Note: For serial interfaces see Fig. 6/40.
Fig. 6/45 Connection diagram

6/38 Siemens SIP · Edition No. 8

Distance Protection 7SA522
SIPROTEC 7SA522 distance protection relay for transmission lines

Function overview

Protection functions · N on-switched distance protection with 6 measuring systems
(21/21N) · H igh resistance ground (earth)-fault protection for single- and
three-pole tripping (50N/51N/67N) · Tele (pilot) protection (85) · Fault locator (FL) · Power swing detection/tripping (68/68T) · Phase-overcurrent protection (50/51/67) · STUB bus overcurrent protection (50 STUB) · Switch-onto-fault protection (50HS) · Over/undervoltage protection (59/27) · Over/underfrequency protection (81O/U) · Auto-reclosure (79) · Synchro-check (25) · Breaker failure protection (50BF)

LSP2309-afpen.tif

Fig. 6/46 SIPROTEC 7SA522 distance protection relay
Description
The SIPROTEC 7SA522 relay provides full-scheme distance protection and incorporates all functions usually required for the protection of a power line. The relay is designed to provide fast and selective fault clearance on transmission and subtransmission cables and overhead lines with or without series capacitor compensation. The power system star point can be solid or resistance grounded (earthed), resonant-grounded via Peterson coil or isolated. The 7SA522 is suitable for single-pole and three-pole tripping applications with and without tele (pilot) protection schemes.
The 7SA522 incorporates several protective functions usually required for transmission line protection.
High-speed tripping time
Suitable for cables and overhead lines with or without series capacitor compensation
Self-setting power swing detection for power swing frequencies up to 7 Hz
Digital relay-to-relay communication for two and three terminal topologies
Adaptive auto-reclosure (ADT)

Control functions · Commands for control of CB and isolators
Monitoring functions · Trip circuit supervision (74TC) · Self-supervision of the relay · Measured-value supervision · Event logging/fault logging · Oscillographic fault recording · Switching statistics
Front design · User-friendly local operation with numeric keys · LEDs for local alarm · PC front port for convenient relay setting · Function keys
Communication interfaces · Front interface for connecting a PC · System interface for connecting to a control system via vari-
ous protocols IEC 61850 Ethernet IEC 60870-5-103 protocol PROFIBUS DP DNP 3 · 2 serial protection data interfaces for tele (pilot) protection · Rear-side service/modem interface · Time synchronization via IRIG B or DCF77 or system interface

1 2 3 4 5 6 7 8 9 10 11 12 13

Hardware
· Binary inputs: 8/16/24 · Output relays: 16/24/32 · High-speed trip outputs: 5 (optional)

14 15

Siemens SIP · Edition No. 8 6/39

Distance Protection 7SA522
Application

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Application

The 7SA522 relay provides full-scheme distance protection and incorporates all functions usually required for the protection of a power line. The relay is designed to provide fast and selective fault clearance on transmission and subtransmission cables and overhead lines with or without series capacitor compensation. This contributes towards improved stability and availability of your electrical power transmission system. The power system star point can be solid or impedance grounded (earthed), resonant-grounded via Peterson coil or isolated. The 7SA522 is suitable for single and three-pole tripping applications with and without tele (pilot) protection schemes.

The effect of apparent impedances in

unfaulted fault loops is eliminated by a

Fig. 6/47 Single-line diagram

sophisticated and improved method which

uses pattern recognition with symmetrical components and load

compensation. The correct phase selection is essential for selective ANSI

tripping and reliable fault location.

21/21N

During network power swings, an improved power swing block-

ing feature prevents the distance protection from unwanted trip-

ping and optionally provides controlled tripping in the event of

50N/51N/67N

loss of synchronism (out of step). This function guarantees power

transmission even under critical network operating conditions.

50/51/67

Cost-effective power system management
The SIPROTEC 4 units are numerical relays which also provide control and monitoring functions and therefore support the user in view of a cost-effective power system management. The security and reliability of power supply is increased as a result of minimizing the use of hardware.
The local operation has been designed according to ergonomic criteria. Large, easy-to-read backlit displays are provided.
The SIPROTEC 4 units have a uniform design and a degree of functionality which represents a benchmark-level of performance in protection and control. If the requirements for protection, control and interlocking change, it is possible in the majority of the cases to implement such changes by means of parameterization using DIGSI 4 without having to change the hardware.

50 STUB 68/68T 85/21 27WI 85/67N 50HS 50BF 59/27 81O/U 25

The use of powerful microcontrollers and the application of

digital measured-value conditioning and processing largely sup-

presses the influence of higher-frequency transients, harmonics

74TC

and DC components.

Features · High speed tripping time

· Suitable for cables and overhead lines with or without series capacitor compensation

· Self setting power swing detection fo frequencies up to 7 Hz

· Digital relay-to-relay communication for two and three terminal topologies

· Adaptive auto-reclosure (ADT)

Protection functions Distance protection Fault locator Directional earth(ground)-fault protection Backup overcurrent protection STUB-bus overcurrent stage Power swing detection/tripping Teleprotection for distance protection Weak-infeed protection Teleprotection for earth(ground)-fault protection Switch-onto-fault protection Breaker-failure protection Overvoltage/undervoltage protection Over/underfrequency protection Synchro-check Auto-reclosure Trip circuit supervision Lockout (CLOSE command interlocking)

6/40 Siemens SIP · Edition No. 8

Distance Protection 7SA522
Construction

Construction

Connection techniques and housing

with many advantages

½ and -rack sizes

These are the available housing widths

of the SIPROTEC 7SA522 relays, referred

to a 19" module frame system. This

means that previous models can always

be replaced. The height is a uniform

245 mm for flush-mounting housings and

266 mm for surface-mounting housings

for all housing widths. All cables can be

connected with or without ring lugs. Plugin terminals are available as an option.

LSP2310-afpen.tif

It is thus possible to employ prefabricated

cable harnesses. In the case of surface

mounting on a panel, the connection terminals are located above and below

in the form of screw-type terminals. The

communication interfaces are located in a Fig. 6/48 Housing widths ½ × 19" and × 19"

sloped case at the top and bottom of the housing.

LSP2174-afp.tif LSP2166-afp.tif

Fig. 6/49 Rear view with screw-type terminals Fig. 6/50 Rear view with terminal covers and

and serial interfaces

wiring

10 11

15
Siemens SIP · Edition No. 8 6/41

Distance Protection 7SA522
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Protection functions

Distance protection (ANSI 21, 21N)
The main function of the 7SA522 is a full-scheme distance protection. By parallel calculation and monitoring of all six impedance loops, a high degree of sensitivity and selectivity is achieved for all types of faults. The shortest tripping time is less than one cycle. Single-pole and three-pole tripping is possible. The distance protection is suitable for cables and overhead lines with or without series capacitor compensation.
Mho and quadrilateral characteristics
The 7SA522 relay provides quadrilateral as well as mho zone characteristics. Both characteristics can be used separately for phase and ground (earth) faults. Resistance ground (earth) faults can, for instance, be covered with the quadrilateral characteristic and phase faults with the mho characteristic.
Load zone
In order to guarantee a reliable discrimination between load operation and short-circuit - especially on long high loaded lines - the relay is equipped with a selectable load encroachment characteristic. Impedances within this load encroachment characteristic prevent the distance zones from unwanted tripping.
Absolute phase-selectivity
The 7SA522 distance protection incorporates a well-proven, highly sophisticated phase selection algorithm. The pickup of unfaulted loops is reliably eliminated to prevent the adverse influence of currents and voltages in the fault-free loops. This phase selection algorithm achieves single-pole tripping and correct distance measurement in a wide application range.
Parallel line compensation
The influence of wrong distance measurement due to parallel lines can be compensated by feeding the neutral current of the parallel line to the relay. Parallel line compensation can be used for distance protection as well as for the fault locator.
7 distance zones
Six independant distance zones and one separate overreach zone are available. Each distance zone has dedicated time stages, partly separate for single-phase or multi-phase faults. Ground (earth) faults are detected by monitoring the neutral current 3I0 and the zero-sequence voltage 3V0.
The quadrilateral tripping characteristic permits separate setting of the reactance X and the resistance R. The resistance section R can be set separately for faults with and without ground involvement. This characteristic has therefore an optimal performance in case of faults with fault resistance. The distance zones can be set forward, reverse or non-directional. Sound phase polarization and voltage memory provides a dynamically unlimited directional sensitivity.
Mho
The mho tripping characteristic provides sound phase respectively memory polarization for all distance zones. The diagram shows characteristic without the expansion due to polarizing. During a forward fault the polarizing expands the mho circle towards the source so that the origin is included. This mho circle expansion guarantees safe and selective operation for all types of faults, even for close-in faults.

Fig. 6/51 Distance protection: quadrilateral characteristic
Fig. 6/52 Distance protection: mho characteristic Elimination of interference signals Digital filters render the unit immune to interference signals contained in the measured values. In particular, the influence of DC components, capacitive voltage transformers and frequency changes is considerably reduced. A special measuring method is employed in order to assure protection selectivity during saturation of the current transformers. Measuring voltage monitoring Tripping of the distance protection is blocked automatically in the event of failure of the measuring voltage, thus preventing spurious tripping. The measuring voltage is monitored by the integrated fuse failure monitor. Distance protection is blocked if either the fuse failure monitor or the auxiliary contact of the voltage transformer protection switch operates and, in this case, the EMERGENCY definite-time overcurrent protection can be activated.

6/42 Siemens SIP · Edition No. 8

Distance Protection 7SA522
Protection functions

Fault locator

The integrated fault locator calculates the fault impedance and the distance-

to-fault. The result is displayed in ohms,

miles, kilometers or in percent of the

line length. Parallel line and load current compensation is also available.

Power swing detection (ANSI 68, 68T)

Dynamic transient reactions, for instance short-circuits, load fluctuations, auto-

reclosures or switching operations can

cause power swings in the transmission

LSP2311-afp.tif

network. During power swings, large

currents along with small voltages can

cause unwanted tripping of distance

protection relays. To avoid uncontrolled

tripping of the distance protection and

to achieve controlled tripping in the event of loss of synchronism, the 7SA522 Fig. 6/53 Power swing current and voltage wave forms

relay is equipped with an efficient power

swing detection function. Power swings

can be detected under symmetrical load conditions as well as during single-pole

auto-reclosures.

Tele (pilot) protection for distance protection (ANSI 85-21)

A teleprotection function is available for fast clearance of faults up to 100 % of the line length. The following operating modes may be selected:

PUTT, permissive underreaching zone transfer trip

LSP2312-afp.tif

POTT, permissive overreaching zone transfer trip

UNBLOCKING

BLOCKING

DUTT, direct underreaching zone transfer trip (together with Direct Transfer Trip function)

Fig. 6/54 Power swing circle diagram

The carrier send and receive signals are available as binary inputs and outputs and can be freely assigned to each physical relay input or output. At least one channel is required for each direction.
Common transmission channels are power-line carrier, microwave radio and fiber-optic links. A serial protection data interface for direct connection to a digital communication network or fiber-optic link is available as well.
7SA522 also permits the transfer of phase-selective signals. This feature is particularly advantageous as it ensures reliable singlepole tripping, if two single-pole faults occur on different lines. The transmission methods are suitable also for lines with three ends (three-terminal lines).

Phase-selective transmission is also possible with multi-end applications, if some user-specific linkages are implemented by way of the integrated CFC logic. During disturbances in the transmission receiver or on the transmission circuit, the teleprotection function can be blocked by a binary input signal without losing the zone selectivity. The control of the overreach zone Z1B (zone extension) can be switched over to the auto-reclosure function. A transient blocking function (Current reversal guard) is provided in order to suppress interference signals during tripping of parallel lines.
Direct transfer tripping
Under certain conditions on the power system it is necessary to execute remote tripping of the circuit-breaker. The 7SA522 relay is equipped with phase-selective "external trip inputs" that can be assigned to the received inter-trip signal for this purpose.

7 8 9 10 11 12 13 14

Siemens SIP · Edition No. 8 6/43

Distance Protection 7SA522
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Weak-infeed protection: echo and/or trip (ANSI 27 WI)
To prevent delayed tripping of permissive schemes during weak or zero infeed situations, an echo function is provided. If no fault detector is picked up at the weak-infeed end of the line, the signal received here is returned as echo to allow accelerated tripping at the strong infeed end of the line. It is also possible to initiate tripping at the weak-infeed end. A phase- selective 1-pole or 3-pole trip is issued if a permissive trip signal (POTT or Unblocking) is received and if the phase-ground voltage drops correspondingly. As an option, the weak infeed logic can be equipped according to a French specification.

Directional ground(earth)-fault protection for highresistance faults (ANSI 50N, 51N, 67N)
In grounded (earthed) networks, it may happen that the distance protection sensitivity is not sufficient to detect highresistance ground (earth) faults. The 7SA522 protection relay therefore has protection functions for faults of this nature.
The ground (earth)-fault overcurrent protection can be used with 3 definite-time stages and one inverse-time stage (IDMT). A 4th definite-time stage can be applied instead of the one inverse-time stage.
Inverse-time characteristics according to IEC 60255-3 and ANSI/ IEEE are provided (see "Technical data"). An additional logarithmic inverse-time characteristic is also available.
The direction decision can be determined by the neutral current and the zero-sequence voltage or by the negative-sequence components V2 and I2. In addition or as an alternative to the directional determination with zero-sequence voltage, the starpoint current of an grounded (earthed) power transformer may also be used for polarization. Dual polarization applications can therefore be fulfilled.
Alternatively, the direction can be determined by evaluation of zero-sequence power. Each overcurrent stage can be set in forward or reverse direction or for both directions (non-directional).
As an option, the 7SA522 relay can be provided with a sensitive neutral (residual) current transformer. This feature provides a measuring range for the neutral (residual) current from 5 mA to 100 A with a nominal relay current of 1 A and from 5 mA to 500 A with a nominal relay current of 5 A. Thus the ground (earth)- fault overcurrent protection can be applied with extreme sensitivity.
The function is equipped with special digital filter algorithms, providing the elimination of higher harmonics. This feature is particularly important for low zero-sequence fault currents which usually have a high content of 3rd and 5th harmonics. Inrush stabilization and instantaneous switch-onto-fault trip can be activated separately for each stage as well.
Different operating modes can be selected. The ground(earth)fault protection is suitable for three-phase and, optionally, for single-phase tripping by means of a sophisticated phase selector. It may be blocked during the dead time of single-pole autoreclose cycles or during pickup of the distance protection.

Fig. 6/55 Normal inverse

( ) t =

0, 14

0, 02

I /Ip -1

Tele (pilot) protection for directional ground(earth)-fault protection (ANSI 85-67N)
The directional ground(earth)-fault overcurrent protection can be combined with one of the following teleprotection schemes: · Directional comparison · BLOCKING · UNBLOCKING
The transient blocking function (current reversal guard) is also provided in order to suppress interference signals during tripping of parallel lines.
The pilot functions for distance protection and for ground (earth)-fault protection can use the same signaling channel or two separate and redundant channels.
Backup overcurrent protection (ANSI 50, 50N, 51, 51N, 67)
The 7SA522 provides a backup overcurrent protection. Two definite-time stages and one inverse-time stage (IDMTL) are available, separately for phase currents and for the neutral (residual) current.
The application can be extended to a directional overcurrent protection (ANSI 67) by taking into account the decision of the available direction detection elements.
Two operating modes are selectable. The function can run in parallel to the distance protection or only during failure of the voltage in the VT secondary circuit (emergency operation).
The secondary voltage failure can be detected by the integrated fuse failure monitor or via a binary input from a VT miniature circuit-breaker (VT m.c.b. trip).
Inverse-time characteristics according to IEC 60255-3 and ANSI/ IEEE are provided (see "Technical data").

6/44 Siemens SIP · Edition No. 8

Distance Protection 7SA522
Protection functions

STUB bus overcurrent protection (ANSI 50(N)-STUB)
The STUB bus overcurrent protection is a separate definite-time overcurrent stage. It can be activated from a binary input signalling that the line isolator (disconnector) is open. Settings are available for phase and ground(earth)-faults.
Instantaneous high-speed switch-onto-fault overcurrent protection (ANSI 50HS)
Instantaneous tripping is possible when energizing a faulty line. In the event of large fault currents, the high-speed switch-ontofault overcurrent stage can initiate very fast 3-pole tripping.
With lower fault currents, instantaneous tripping after switchonto-fault is also possible with the overreach distance zone Z1B or just with pickup in any zone.
The switch-onto-fault initiation can be detected via the binary input "manual close" or automatically via measurement.
Overvoltage protection, undervoltage protection (ANSI 59, 27)
A voltage rise can occur on long lines that are operating at no-load or that are only lightly loaded. The 7SA522 contains a number of overvoltage measuring elements. Each measuring element is of two-stage design. The following measuring elements are available: · Phase-to-ground overvoltage · Phase-to-phase overvoltage · Zero-sequence overvoltage · The zero-sequence voltage can be connected to the 4th volt-
age input or be derived from the phase voltages. · Positive-sequence overvoltage of the local end or calculated
for the remote end of the line (compounding). · Negative-sequence overvoltage
Tripping by the overvoltage measuring elements can be effected either at the local circuit-breaker or at the remote station by means of a transmitted signal.
The 7SA522 is fitted, in addition, with three two-stage undervoltage measuring elements: · Phase-to-ground undervoltage · Phase-to-phase undervoltage · Positive-sequence undervoltage
The undervoltage measuring elements can be blocked by means of a minimum current criterion and by means of binary inputs.
Frequency protection (ANSI 81O/U)
Frequency protection can be used for over-frequency and underfrequency protection. Unwanted frequency changes in the network can be detected and the load can be removed at a specified frequency setting. Frequency protection can be used over a wide frequency range (45 to 55, 55 to 65 Hz). There are four elements (selectable as overfrequency or underfrequency) and each element can be delayed separately.

Breaker failure protection (ANSI 50BF)
The 7SA522 relay incorporates a two-stage circuit-breaker failure protection to detect failures of tripping command execution, for example due to a defective circuit-breaker. The current detection logic is phase-segregated and can therefore also be used in single-pole tripping schemes.
If the fault current is not interrupted after a time delay has expired, a retrip command or the busbar trip command will be generated. The breaker failure protection can be initiated by all integrated protection functions as well as by external devices via binary input signals.
Auto-reclosure (ANSI 79)
The 7SA522 relay is equipped with an auto-reclose function (AR). The function includes several operating modes:
· 3-pole auto-reclosure for all types of faults; different dead times are available depending the type of fault
· 1-pole auto-reclosure for 1-phase faults, no reclosing for multi-phase faults
· 1-pole auto-reclosure for 1-phase faults and for 2-phase faults without ground, no reclosing for multi-phase faults
· 1-pole auto-reclosure for 1-phase and 3-pole auto-reclosing for multi-phase faults
· 1-pole auto-reclosure for 1-phase faults and 2-phase faults without ground and 3-pole auto-reclosure for other faults
· Multiple-shot auto-reclosure
· Interaction with an external device for auto-reclosure via binary inputs and outputs
· Control of the integrated AR function by external protection
· Interaction with the internal or an external synchro-check
· Monitoring of the circuit-breaker auxiliary contacts
In addition to the above-mentioned operating modes, several other operating principles can be employed by means of the integrated programmable logic (CFC).
Integration of auto-reclosure in the feeder protection allows evaluation of the line-side voltages. A number of voltagedependent supplementary functions are thus available:
· DLC By means of dead-line check, reclosure is effected only when the line is deenergized (prevention of asynchronous breaker closure).
· ADT The adaptive dead time is employed only if auto-reclosure at the remote station was successful (reduction of stress on equipment).
· RDT Reduced dead time is employed in conjunction with autoreclosure where no tele-protection method is employed:
When faults within the zone extension, but external to the protected line, are switched off for rapid auto-reclosure (RAR), the RDT function decides on the basis of measurement of the return voltage from the remote station which has not tripped whether or not to reduce the dead time.

1 2 3 4 5 6 7 8 9 10 11 12 13 14

15
Siemens SIP · Edition No. 8 6/45

Distance Protection 7SA522
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12

Synchronism check (ANSI 25)
Where two network sections are switched in by control command or following a 3-pole, it must be ensured that both network sections are mutually synchronous. For this purpose, a synchronism-check function is provided. After verification of the network synchronism the function releases the CLOSE command. Alternatively, reclosing can be enabled for different criteria, e.g., checking that the busbar or line is not carrying a voltage (dead line or dead bus).Fuse failure monitoring and other supervision functions
The 7SA522 relay provides comprehensive monitoring functions covering both hardware and software. Furthermore, the measured values are continuously checked for plausibility. Therefore the current and voltage transformers are also included in this monitoring system.
If any measured voltage is not present due to short-circuit or open circuit in the voltage transformer secondary circuit, the distance protection would respond with an unwanted trip due to this loss of voltage. This secondary voltage interruption can be detected by means of the integrated fuse failure monitor. Immediate blocking of distance protection and switching to the backup-emergency protection is provided for all types of secondary voltage failures.
Additional measurement supervision functions are
· Symmetry of voltages and currents
· Broken-conductor supervision
· Summation of currents and voltages
· Phase-sequence supervision
Directional power protection
The 7SA522 has a function for detecting the power direction by measuring the phase angle of the positive-sequence system's power. Fig. 6/57 shows an application example displaying negative active power. An indication is issued in the case when the measured angle (S1) of the positive-sequence system power is within the P - Q - level sector. This sector is between angles A and B. Via CFC the output signal of the directional monitoring can be linked to the "Direct Transfer Trip (DTT)" function and thus, as reverse power protection, initiate tripping of the CB.
Fig.6/58 shows another application displaying capacitive reactive power. In the case of overvoltage being detected due to long lines under no-load conditions it is possible to select the lines where capacitive reactive power is measured.

Negative active power (-P)

j Q

Positive active

power (+P)

j A P
j B S1

LSA_5018a en eps

Fig. 6/56 Monitoring of active power direction

j Q

Inductive (+Q)

LSA_5019a en eps

j A P
j B
S1
Capacitive (-Q)
Fig. 6/57 Monitoring of reactive power
Trip circuit supervision (ANSI 74TC) One or two binary inputs for each circuit-breaker pole can be used for monitoring the circuit-breaker trip coils including the connecting cables. An alarm signal is issued whenever the circuit is interrupted.
Lockout (ANSI 86) Under certain operating conditions, it is advisable to block CLOSE commands after a TRIP command of the relay has been issued. Only a manual "Reset" command unblocks the CLOSE command. The 7SA522 is equipped with such an interlocking logic.

15
6/46 Siemens SIP · Edition No. 8

Distance Protection 7SA522
Protection functions

Commissioning and fault event

analyzing Special attention has been paid to com-

missioning. All binary inputs and outputs

can be displayed and activated directly.

This can simplify the wiring check significantly for the user. The operational

and fault events and the fault records are

clearly arranged. For applications with

serial protection data interface, all cur-

rents, voltages and phases are available

via communication link at each local unit,

displayed at the front of the unit with

DIGSI 4 or with WEB Monitor.

A common time tagging facilitates the comparison of events and fault records.

LSP2818.tif

WEB Monitor Internet technology

simplifies visualization In addition to the universal DIGSI 4

Fig. 6/58 Web Monitor: Display of the protection direction

operating program, the relay contains

a WEB server that can be accessed via a

telecommunication link using a browser (e.g. Internet Explorer). The advantage of

this solution is to operate the unit with

standard software tools and at the same

time make use of the Intranet/Internet

infrastructure. Apart from numeric values,

graphical displays in particular provide

clear information and a high degree of

operating reliability. Of course, it is also

possible to call up detailed measured value displays and annunciation buffers.

By emulation of the integrated unit opera-

tion on the PC it is also possible to adjust

selected settings for commissioning purposes.

LSP2820.tif

Fig. 6/59 Web monitor: Supported commissioning by phasor diagram

11 12

15
Siemens SIP · Edition No. 8 6/47

Distance Protection 7SA522
Communication

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Communication

With respect to communication, particular emphasis is placed on the customer requirements in energy automation:
· Every data item is time-stamped at the source, i.e. where it originates.
· The communication system automatically handles the transfer of large data blocks (e.g. fault recordings or parameter data files). The user has access to these features without any additional programming effort.
· For the safe execution of a control command the corresponding data telegram is initially acknowledged by the device which will execute the command. After the release and execution of the command a feedback signal is generated. At every stage of the control command execution particular conditions are checked. If these are not satisfied, command execution may be terminated in a controlled manner.
The units offer a high degree of flexibility by supporting different standards for connection to industrial and power automation systems. By means of the communication modules, on which the protocols run, exchange and retrofit is possible. Therefore, the units will also in future allow for optimal adaptation to changing communication infrastructure such as the application of Ethernet networks which are already widely applied in the power supply sector.

Fig. 6/60 IEC 60870-5-103 star-type RS232 copper conductor connection or fiber-optic connection

Service/modem interface
By means of the RS 485/RS 232 interface, it is possible to efficiently operate a number of protection units centrally via DIGSI 4. Remote operation is possible on connection of a modem. This offers the advantage of rapid fault clarification, especially in the case of unmanned power plants. With the optical version, centralized operation can be implemented by means of a star coupler.
Time synchronization
The time synchronization interface is a standard feature in all units. The supported formats are IRIG-B and DCF77.
Reliable bus architecture · RS485 bus
With this data transmission via copper conductors, electromagnetic fault influences are largely eliminated by the use of twisted-pair conductors. Upon failure of a unit, the remaining system continues to operate without any problems.
· Fiber-optic double ring circuit The fiber-optic double ring circuit is immune to electromagnetic interference. Upon failure of a section between two units, the communication system continues to operate without disturbance. It is usually impossible to communicate with a unit that has failed. Should the unit fail, there is no effect on the communication with the rest of the system.

Fig. 6/61 Bus structure for station bus with Ethernet and IEC 61850
Retrofitting: Modules for every type of communication
Communication modules for retrofitting are available for the entire SIPROTEC 4 unit range. These ensure that, where different communcation protocols (IEC 61850, IEC 60870-5-103, PROFIBUS, DNP, etc) are required, such demands can be met. For fiber-optic communication, no external converter is required for SIPROTEC 4.
IEC 61850 protocol
The Ethernet-based IEC 61850 protocol is the worldwide standard for protection and control systems used by power supply corporations. Siemens was the first manufacturer to support this standard. By means of this protocol, information can also be exchanged directly between bay units so as to set up simple masterless systems for bay and system interlocking. Access to the units via the Ethernet but is also possible with DIGSI. It is also possible to retrieve operating and fault records as well as fault recordings via a browser. This Web monitor will also provide a few items of unit-specific information in browser windows.

6/48 Siemens SIP · Edition No. 8

Distance Protection 7SA522
Communication

LSP2162-afpen.tif

IEC 60870-5-103 protocol
IEC 60870-5-103 is an internationally standardized protocol for efficient communication with protection relays. IEC 60870-5-103 is supported by a number of protection relay manufacturers and is used worldwide. Supplements for control functions are defined in the manufacturer-specific part of this standard.

PROFIBUS DP
PROFIBUS DP is an industrial communication standard and is supported by a number of PLC and protection relay manufacturers.

Fig. 6/62 820 nm fiber-optic communication module

DNP 3.0
DNP 3.0 (Distributed Network Protocol, Version 3) is an internationally recognized protection and bay unit communication protocol. SIPROTEC 4 units are Level 1 and Level 2 compatible.

Fig. 6/64 RS232/RS485 electrical communication module

LSP2163-afpen.tif

LSP2164-afp.tif

Fig. 6/63 PROFIBUS fiber-optic double ring

communication module

LSP3.01-0021.tif

Fig. 6/65 Fiber-optic Ethernet communication

module for IEC 61850 with integrated Ethernet switch

Fig. 6/66 Communication

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Siemens SIP · Edition No. 8 6/49

Distance Protection 7SA522
Communication

1 2 3 4 5 6 7 8 9 10 11 12 13

Because of the standardized interfaces, SIPROTEC units can also be integrated into systems of other manufacturers or in SIMATIC. Electrical RS485 or optical interfaces are available. The optimum physical data transfer medium can be chosen thanks to optoelectrical converters. Thus, the RS485 bus allows low-cost wiring in the cubicles and an interference-free optical connection to the master can be established.
For IEC 61850, an interoperable system solution is offered with SICAM PAS. Via the 100 Mbits/s Ethernet bus, the units are linked with PAS electrically or optically to the station PC. The interface is standardized, thus also enabling direct connection of units of other manufacturers to the Ethernet bus. With IEC 61850, however, the units can also be used in other manufacturers' systems. Units with an IEC 60870-5-103 interface are connected with PAS via the Ethernet station bus by means of serial/Ethernet converters. DIGSI and the Web monitor can also be used via the same station bus.
Serial protection data interface
The tele (pilot) protection schemes can be implemented using digital serial communication. The 7SA522 is capable of remote relay communication via direct links or multiplexed digital communication networks. The serial protection data interface has the following features:
· Fast phase-selective teleprotection signaling for distance protection, optionally with POTT or PUTT schemes
· Signaling for directional ground(earth)- fault protection directional comparison for high-resistance faults in solidly grounded systems.
· Echo-function
· Two and three-terminal line applications can be implemented without additional logic
· Interclose command transfer with the auto-reclosure "Adaptive dead time" (ADT) mode
· Redundant communication path switchover is possible with the 7SA522 when 2 serial protection data interfaces are installed
· 28 remote signals for fast transfer of binary signals
· Flexible utilization of the communication channels by means of the programmable CFC logic
· Display of the operational measured values of the opposite terminal(s) with phase-angle information relative to a common reference vector
· Clock synchronization: the clock in only one of the relays must be synchronized from an external so called "Absolute Master" when using the serial protection data interface. This relay will then synchronize the clock of the other (or the two other relays in 3 terminal applications) via the protection data interface.
· 7SA522 and 7SA6 can be combined via the protection data interface.

The communication possibilities are identical to those for the line differential protection relays 7SD5 and 7SD610. The following options are available: · FO51), OMA12) module: Optical 820 nm, 2 ST connectors,
FO cable length up to 1.5 km for link to communication networks via communication converters or for direct FO cable connection · FO61), OMA22) module: Optical 820 nm, 2 ST connectors, FO cable length up to 3.5 km, for direct connection via multimode FO cable · FO171): for direct connection up to 24 km3), 1300 nm, for mono-mode fiber 9/125 m, LC-Duplex connector · FO181): for direct connection up to 60 km3), 1300 nm, for mono-mode fiber 9/125 m, LC-Duplex connector · FO191): for direct connection up to 100 km3), 1550 nm, for mono-mode fiber 9/125 m, LC-Duplex connector · FO301): for transmission with the IEEE C37.94 standard
The link to a multiplexed communication network is made by separate communication converters (7XV5662). These have a fiber-optic interface with 820 nm and 2 ST connectors to the protection relay. The link to the communication network is optionally an electrical X21 or a G703.1 interface. If the connection to the multiplexor supports IEEE C37.94 a direct fibre optic connection to the relay is possible using the FO30 module.
For operation via copper wire communication (pilot wires), a modern communication converter for copper cables is available. This operates with both the two-wire and three-wire copper connections which were used by conventional differential protection systems before. The communication converter for copper cables is designed for 5 kV insulation voltage. An additional 20 kV isolation transformer can extend the field of applications of this technique into ranges with higher insulation voltage requirements. With SIPROTEC 4 and the communication converter for copper cables a digital follow-up technique is available for two-wire protection systems (typical 15 km) and all three-wire protection systems using existing copper communication links.
Communication data:
· Supported network interfaces G703.1 with 64 kbit/s; X21/ RS422 with 64 or 128 or 512 kbit/s; IEEE C37.94
· Max. channel delay time 0.1 ms to 30 ms (in steps of 0.1 ms)
· Protocol HDLC
· 32-bit CRC-check according to CCITT and ITU
· Each protection relay possesses a unique relay address
· Continuous communication link supervision: Individual faulty data telegrams do not constitute an immediate danger, if they occur only sporadically. The statistical availability, per minute and hour, of the serial protection data interface can be displayed.
Figure 6/68 shows four applications for the serial protection data interface on a two-terminal line.

14 15
6/50 Siemens SIP · Edition No. 8

1) For flush-mounting housing. 2) For surface-mounting housing. 3) For surface-mounting housing the internal fiber-optic module
(OMA1) will be delivered together with an external repeater.

Distance Protection 7SA522
Communication

Fig. 6/67 Communication topologies for the serial protection data interface on a two-terminal line

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 6/51

Distance Protection 7SA522
Communication

Three-terminal lines can also be protected

with a tele (pilot) protection scheme by using SIPROTEC 4 distance protection

relays. The communication topology may

then be a ring or a chain topology, see

Fig. 6/69. In a ring topology a loss of one

data connection is tolerated by the system. The topology is re-routed to become a

chain topology within less than 100 ms.

To reduce communication links and to

save money for communications, a chain

topology may be generally applied.

Ring topology

10 11

Chain topology Fig. 6/68 Ring or chain communication topology

15
6/52 Siemens SIP · Edition No. 8

Distance Protection 7SA522
Typical connection
1 2 3 4

Fig. 6/69 Example of connection for current and voltage transformers

Alternative current measurement
The 3 phase current transformers are connected in the usual manner. The neutral point is in line direction. I4 is connected to a separate neutral core-balance CT, thus permitting a high sensitive 3I0 measurement.
Note: Terminal Q7 of the I4 transformer must be connected to the terminal of the core balance CT pointing in the same direction as the neutral point of the phase current transformers (in this case in line direction). The voltage connection is effected in accordance with Fig. 66/70, 6/74 or 6/75.

Fig. 6/70 Alternative connection of current transformers for sensitive groundcurrent measuring with core-balance current transformers

6 7 8 9 10

15
Siemens SIP · Edition No. 8 6/53

Distance Protection 7SA522
Typical connection

Alternative current connection

3 phase current transformers with neutral point in the line direction, I4 connected to

a current transformer in the neutral point

of a grounded (earthed) transformer for

directional ground(earth)-fault protection. The voltage connection is effected in

accordance with Fig. 6/70, 6/74 or 6/75.

Alternative current connection

3 phase current transformers with neutral

point in the line direction, I4 connected to

the summation current of the parallel line

for parallel line compensation on overhead

lines. The voltage connection is effected in accordance with Fig. 6/70, 6/74 or 6/75.

Fig. 6/71 Alternative connection of current transformers for measuring neutral current of a grounded (earthed) power transformer

Fig. 6/72 Alternative connection of current transformers for measuring the ground (earth) current of a parallel line

15
6/54 Siemens SIP · Edition No. 8

Alternative voltage connection
3 phase voltage transformers, V4 connected to broken (open) delta winding (Ven) for additional summation voltage monitoring and ground(earth)-fault directional protection. The current connection is effected in accordance with Fig. 6/70, 6/71, 6/72 and 6/73.

Distance Protection 7SA522
Typical connection
1 2 3

Fig. 6/73 Alternative connection of voltage transformers for measuring the displacement voltage (e-n voltage)

Alternative voltage connection

3 phase voltage transformers, V4 con-

nected to busbar voltage transformer for

synchro-check. Note: Any phase-to-phase or phase-to-

ground (earth) voltage may be employed

as the busbar voltage. Parameterization is

carried out on the unit. The current connection is effected in accordance with

Fig. 6/70, 6/71, 6/72 and 6/73.

Fig. 6/74 Alternative connection of voltage transformers for measuring the busbar voltage

10 11

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Siemens SIP · Edition No. 8 6/55

Distance Protection 7SA522
Technical data

1 2 3 4 5 6 7 8 9 10 11 12

General unit data

Analog inputs

Rated frequency

50 or 60 Hz (selectable)

Rated current Inom Rated voltage

1 or 5 A (selectable) 80 to 125 V (selectable)

Power consumption

In CT circuits with Inom = 1 A

Approx. 0.05 VA

In CT circuits with Inom = 5 A

Approx. 0.30 VA

In the CT circuit for high sensitive Approx. 0.05 VA

ground(earth)-fault protection

(refer to ordering code) at 1 A

In VT circuits

Approx. 0.10 VA

Thermal overload capacity

In CT circuits

500 A for 1 s

150 A for 10 s

20 A continuous

In the CT circuit for high sensitive 300 A for 1 s

ground(earth)-fault protection 100 A for 10 s

(refer to ordering code)

15 A continuous

In VT circuits

230 V continuous per phase

Dynamic overload capacity

In CT circuits

1250 A (one half cycle)

In the CT circuit for high sensitive 750 A (one half cycle)

ground(earth)-fault protection

(refer to ordering code)

Auxiliary voltage

Rated auxiliary voltage

DC 24 to 48 V DC 60 to 125 V DC 110 to 250 V and AC 115 V with 50/60 Hz

Permissible tolerance of the rated -20 % to +20 % auxiliary voltage

Max. superimposed AC voltage (peak-to-peak)

15 %

Power consumption During normal operation During pickup with all inputs and outputs activated

Approx. 8 W Approx. 18 W

Bridging time during auxiliary voltage failure
Vaux = 48 V and Vaux 110 V

50 ms

Binary inputs

Quantity Functions are freely assignable

8 or 16 or 24 (refer to ordering code)

Pickup/Reset voltage thresholds DC 19 V/ DC 10 V or DC 88 V/ DC Ranges are settable by means of 44V or DC 176 V/ DC 88 V, bipolar jumpers for each binary input (3 nominal ranges DC 17/73/154 V)

Maximum permissible voltage

DC 300 V

Current consumption, energized Approx. 1.8 mA

Input impulse suppression

220 nF coupling capacitance at 220 V with a recovery time > 60 ms.

Output contacts

Quantity Function can be assigned

8 or 16 or 24 (refer to ordering code)

Switching capacity Make Break, high-speed trip outputs Break, contacts Break, contacts (for resistive load)

1000 W/VA 1000 W/VA 30 VA 40 W

Break, contacts (for = L/R 50 ms)

25 VA

Switching voltage

250 V

Permissible current

30 A for 0.5 s 5 A continuous

Operating time, approx. NO contact NO/NC contact (selectable) Fast NO contact High-speed NO trip outputs

8 ms 8 ms 5 ms < 1 ms

LEDs

RUN (green) ERROR (red) Indication (red), function can be assigned

Quantity 1 1 14

Unit design

Housing

7XP20

Dimension

1/2 x 19" or 1/1 x 19" Refer to ordering code, and see dimension drawings, part 14

Degree of protection acc. to EN 60529

Surface-mounting housing Flush-mounting housing
Front Rear For the terminals

IP 51
IP 51 IP 50 IP 20 with terminal cover put on

Weight Flush-mounting housing ½ x 19" x 19" Surface-mounting housing ½x 19" x 19"

6 kg 10 kg
11 kg 19 kg

15
6/56 Siemens SIP · Edition No. 8

Distance Protection 7SA522
Technical data

Electrical tests Specifications Standards
Insulation tests Standards High-voltage test (routine test)
All circuits except for power supply, binary inputs, high-speed outputs, communication and time synchronization interfaces Auxiliary voltage, binary inputs and high-speed outputs (routine test) only isolated communication interfaces and time synchronization interface (routine test) Impulse voltage test (type test) All circuits except for communication interfaces and time synchronization interface, class III

IEC 60255 (product standards) IEEE Std C37.90.0/.1/.2; UL 508 VDE 0435 Further standards see "Individual functions"
IEC 602555 and 60870-2-1
2.5 kV (r.m.s.), 50 Hz
DC 3.5 kV
500 V (r.m.s.), 50 Hz
5 kV (peak); 1.2/50 µs; 0.5 Ws, 3 positive and 3 negative impulses in intervals of 5 s

EMC tests for noise immunity; type tests

Standards

IEC 60255-6/-22 (product standard) EN 61000-6-2 (generic standard), VDE 0435 part 301 DIN VDE 0435-110

High-frequency test IEC 60255-22-1 class III and VDE 0435 Section 303, class III

2.5 kV (peak); 1 MHz; = 15 ms; 400 surges per s; test duration 2 s, Ri = 200

Electrostatic discharge IEC 60255-22-2 class IV and IEC 61000-4-2, class IV

8 kV contact discharge; 15 kV air discharge; both polarities; 150 pF; Ri = 330

Irradiation with HF field, frequency 10 V/m; 80 to 1000 MHz: 80 % AM;

sweep

1 kHz

IEC 60255-22-3 (report) class III 10 V/m; 800 to 960 MHz: 80 % AM;

1 kHz

IEC 61000-4-3, class III

10 V/m; 1.4 to 2 GHz: 80 % AM; 1 kHz

Irradiation with HF field, single frequencies IEC 60255-22-31, IEC 61000-4-3, class III amplitude/pulse modulated

10 V/m; 80, 160, 450, 900 MHz; 80 % AM; 1 kHz; duty cycle > 10 s 900 MHz; 50 % PM, repetition frequency 200 Hz

Fast transient disturbance/bursts IEC 60255-22-4 and IEC 61000-4-4, class IV

4 kV; 5/50 ns; 5 kHz; burst length = 15 ms; repetition rate 300 ms; both polarities; Ri = 50 ; test duration 1 min

High-energy surge voltages (SURGE), IEC 61000-4-5 installation class III Auxiliary supply

Impulse: 1.2/50 µs
Common mode: 2 kV; 12 ; 9 µF Differential mode:1 kV; 2 ; 18 µF

Analog measurement inputs, binary inputs, relays output

Common mode: 2 kV; 42 ; 0.5 µF Differential mode: 1 kV; 42 ; 0.5 µF

Line-conducted HF, amplitude- 10 V; 150 kHz to 80 MHz; 80 % AM; modulated, IEC 61000-4-6, class III 1 kHz

Power system frequency magnetic field IEC 61000-4-8, class IV; IEC 60255-6

30 A/m continuous; 300 A/m for 3 s;
50 Hz 0.5 mT; 50 Hz

Oscillatory surge withstand capability, IEEE Std C37.90.1
Fast transient surge withstand capability, IEEE Std C37.90.1
Radiated electromagnetic interference IEEE Std C37.90.2

2.5 kV (peak); 1 MHz = 50 s; 400 surges per second, test duration 2 s, Ri = 200
4 kV; 5/50 ns; 5 kHz; burst length = 15 ms repition rate 300 ms, ; both polarities; test duration 1 min; Ri = 50
35 V/m; 25 to 1000 MHz, amplitude and pulse-modulated

Damped oscillations IEC 60694, IEC 61000-4-12

2.5 kV (peak value); polarity alternating 100 kHz; 1 MHz; 10 and 50 MHz; Ri = 200

EMC tests for noise emission; type test

Standard

EN 61000-6-3 (generic standard)

Radio noise voltage to lines, only 150 kHz to 30 MHz

auxiliary voltage

Limit class B

IEC-CISPR 22

Radio interference field strength 30 to 1000 MHz

IEC-CISPR 22

Limit class B

Harmonic currents on the network Class A limits are observed lead at AC 230 V, IEC 61000-3-2

Voltage fluctuations and flicker on the network incoming feeder at AC 230 V, IEC 61000-3-3

Limits are observed

1 2 3 4 5 6 7 8 9 10 11 12 13 14

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Siemens SIP · Edition No. 8 6/57

Distance Protection 7SA522
Technical data

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Mechanical stress test

Vibration, shock stress and seismic vibration

During operation

Standards

IEC 6025521 and IEC 600682

Vibration IEC 60255211, class 2 IEC 6006826

Sinusoidal 10 to 60 Hz: ± 0.075 mm amplitude; 60 to 150 Hz: 1 g acceleration frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes

Shock IEC 60255212, class 1 IEC 60068227

Semi-sinusoidal Acceleration 5 g, duration 11 ms, 3 shocks on each of the 3 axes in both directions

Seismic vibration IEC 60255212, class 1 IEC 6006833

During transport

Standards

IEC 6025521 and IEC 600682

Vibration IEC 60255211, class 2 IEC 6006826

Sinusoidal 5 to 8 Hz: ± 7.5 mm amplitude; 8 to 150 Hz: 2 g acceleration Frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes

Shock IEC 60255212, class 1 IEC 60068227

Semi-sinusoidal Acceleration 15 g, duration 11 ms, 3 shocks on each of the 3 axes in both directions

Continuous shock IEC 60255212, class 1 IEC 60068229

Semi-sinusoidal Acceleration 10 g, duration 16 ms, 1000 shocks on each of the 3 axes in both directions

Climatic stress tests

Standard

IEC 60255-6

Temperatures

Type-tested acc. to IEC 60068-2-1 -25 °C to +85 °C / -13 °F to +185 °F and -2, test Bd

Temporarily permissible operating -20 °C to +70 °C / -4 °F to +158 °F temperature, tested for 96 h (Legibility of display may be impaired above +55 °C / +131 °F)

Recommended permanent operating temperature acc. to IEC 60255-6
Limiting temperature during permanent storage

-5 °C to +55 °C / +23 °F to +131 °F -25 °C to +55 °C / -13 °F to 131 °F

Limiting temperature during -25 °C to +70 °C / -13 °F to +158 °F transport

Humidity

Permissible humidity stress:

Annual average on 75 % relative

It is recommended to arrange the humidity; on 56 days per year up to

units in such a way that they are 93 % relative humidity; condensation

not exposed to direct sunlight or is not permitted.

pronounced temperature changes

that could cause condensation.

Futher information can be found in the current manual at: www.siemens.com/siprotec

6/58 Siemens SIP · Edition No. 8

Distance Protection 7SA522
Selection and ordering data

Description 7SA522 distance protection relay or transmission lines

Current transformer Iph = 1 A1), IGnd = 1 A1) (min. = 0.05 A) Iph = 1 A1), IGnd = high sensitive (min. = 0.003 A) Iph = 5 A1), IGnd = 5 A (min. = 0.25 A) Iph = 5 A1), IGnd = high sensitive (min. = 0.003 A)

Rated auxiliary voltage (power supply, binary inputs) DC 24 to 48 V, binary input threshold DC 17 V 3) DC 60 to 125 V 2), binary input threshold DC 17 V 3) DC 110 to 250 V 2), AC 115 V, binary input threshold DC 73 V 3) DC 220 to 250 V 2), AC 115 V, binary input threshold DC 154 V 3)

Binary/ indication inputs

Signal/ command outputs incl. live status contact

Fast relay

Highspeed trip output

Housing width referred to 19"

Flushmounting housing/ screw-type terminals

Flushmounting housing/ plug-in terminals

Surfacemounting housing/ screw-type terminals

15 5

18 10

Region-specific default settings/language settings (language selectable) Region DE, language: German Region World, language: English (GB) Region US, language: English (US) Region FR, language: French Region World, language: Spanish Region World, language: Italian Region World, language: Russian Region World, language: Polish

Order No.

7SA522 - -

see following

pages

6
4

J C

N Q

Regulation on region-specific presettings and function versions:
Region DE: preset to f = 50 Hz and line length in km, only IEC, directional ground-(earth) fault protection: no logarithmic inverse characteristic, no direction decision with zero-sequence power Sr
Region US: preset to f = 60 Hz and line length in miles, ANSI inverse characteristic only, directional ground-(earth) fault protection: no logarithmic inverse characteristic, no direction decision with zero-sequence power Sr, no U0 inverse characteristic
Region World: p reset to f = 50 Hz and line length in km, directional ground-(earth) fault protection: no direction decision with zero-sequence Sr, no U0 inverse characteristic
Region FR:preset to f = 50 Hz and line length in km, directional ground-(earth) fault protection: no U0 inverse characteristic, no logarithmic inverse characteristic, weak infeed logic selectable between French specification and World specification.

1) Rated current can be selected by means of jumpers.
2) T ransition between the three auxiliary voltage ranges can be selected by means of jumpers.
3) T he binary input thresholds can be selected by means of jumpers.

14 15

Siemens SIP · Edition No. 8 6/59

Distance Protection 7SA522
Selection and ordering data

1 2 3 4 5 6 7 8 9 10 11

Description 7SA522 distance protection relay for transmission lines
Port B Empty System interface, IEC 60870-5-103 protocol, electrical RS232 System interface, IEC 60870-5-103 protocol, electrical RS485 System interface, IEC 60870-5-103 protocol, optical 820 nm, ST connector System interface, PROFIBUS DP, electrical RS485 System interface, PROFIBUS DP, optical 820 nm, double ring, ST connector1) System interface, DNP 3.0, electrical RS485 System interface, DNP 3.0, optical 820 nm, ST connector1) System interface, IEC 61850, 100 Mbit/s Ethernet, electrical, duplicate,RJ45 plug connectors System interface, IEC 61850, 100 Mbit/s Ethernet, optical, double, LC connector4)
Port C and/or Port D Empty Port C: DIGSI/modem, electrical RS232; Port D: empty Port C: DIGSI/modem, electrical RS485; Port D: empty Port C: DIGSI/modem, optical 820 nm, ST connector; Port D: empty
With Port D
Port C Empty DIGSI/modem, electrical RS232 DIGSI/modem, electrical RS485 DIGSI/modem, optical 820 nm, ST connector
Port D Protection data interface: optical 820 nm, two ST connectors, FO cable length up to 1.5 km For direct connection via multi-mode FO cable or communication networks2) Protection data interface: optical 820 nm, two ST connectors, FO cable length up to 3.5 km For direct connection via multi-mode FO cable Protection data interface: optical 1300 nm, LC-Duplex connector FO cable length up to 24 km for direct connection via mono-mode FO cable3) Protection data interface: optical 1300 nm, LC-Duplex connector FO cable length up to 60 km for direct connection via mono-mode FO cable3) 5) Protection data interface: optical 1550 nm, LC-Duplex connector FO cable length up to 100 km for direct connection via mono-mode FO cable3) 6) FO30 optical 820 nm, 2 ST-connectors, length of optical fibre up to 1.5 km for multimode fibre, for communication networks with IEEE C37.94 interface or direct optical fibre connection (not available for surface-mounted housing)

Order No.

Order Code

7SA522 - -

see

following

1 pages

L 0A

L 0B

L 0G

L 0H

L 0R

L 0S

0 1 2 3

A B G H J
S

13 14 15

1) Optical double ring interfaces are not available with surfacemounting housings. Please, order the version with RS485 interface and a separate electrical/ optical converter.
2) S uitable communication converters 7XV5662 (optical to G703.1/X21/RS422 or optical to pilot wire or optical to ISDN) see "Accessories".
3) For surface-mounting housing applications an internal fiber-optic module 820 nm will be delivered in combination with an external repeater.
4) For surface-mounting housing applications please order

the relay with electrical Ethernet interface and use a separate fiber-optic switch.
5) For distances less than 25 km, two optical attenuators 7XV5107-0AA00 are required to avoid optical saturation of the receiver element.
6) For distances less than 50 km, two optical attenuators 7XV5107-0AA00 are required to avoid optical saturation of the receiver element.

6/60 Siemens SIP · Edition No. 8

Distance Protection 7SA522
Selection and ordering data

Description 7SA522 distance protection relay for transmission lines
Functions 1 and Port E Trip mode 3-pole; Port E: empty Trip mode 3-pole; BCD-coded output for fault location, Port E: empty Trip mode 1 and 3-pole; Port E: empty Trip mode 1 and 3-pole; BCD-coded output for fault location, Port E: empty
With Port E
Functions 1 Trip mode 3-pole Trip mode 3-pole; BCD-coded output for fault location Trip mode 1 and 3-pole Trip mode 1 and 3-pole; BCD-coded output for fault location
Port E Protection data interface: FO5: Optical 820 nm, 2 ST connectors, FO cable length up to 1.5 km for communication networks1) or direct connection via multi-mode FO cable FO6: Optical 820 nm, 2 ST connectors, FO cable length up to 3.5 km for direct connection via multi-mode FO cable FO17: Optical 1300 nm, LC-Duplex connector FO cable length up to 24 km for direct connection via mono-mode FO cable2) FO18: Optical 1300 nm, LC-Duplex connector FO cable length up to 60 km or direct connection via mono-mode FO cable2) 3) FO19: Optical 1550 nm, LC-Duplex connector FO cable length up to 100 km for direct connection via mono-mode FO cable2) 4) FO30: Optical 820 nm, 2 ST connectors, length of optical fibre up to 1.5 km for multimode fibre, for communication networks with IEEE C37.94 interface or direct optical fibre connection (not available for surface-mounted housing)

Order No.

Order code

7SA522 - -

see 0 next

1 page 4

4 5

S
8

1) Suitable communication converters 7XV5662 (optical to G703.1/X21/ RS422 or optical to pilot wire) see "Accessories".
2) For surface-mounting housing applications an internal fiber-optic module 820 nm will be delivered in combination with an external repeater.

3) F or distances less than 25 km, two optical attenuators 7XV5107-0AA00 are required to avoid optical saturation of the receiver element.
4) For distances less than 50 km, two optical attenuators 7XV5107-0AA00 are required to avoid optical saturation of the receiver element.

14 15

Siemens SIP · Edition No. 8 6/61

Distance Protection 7SA522
Selection and ordering data

1 2 3 4 5 6 7 8 9 10 11 12

Description 7SA522 distance protection relay for transmission lines

Functions 2 Distance protection characteristic (ANSI 21, 21N) Quadrilateral Quadrilateral and/or MHO Quadrilateral Quadrilateral and/or MHO Quadrilateral Quadrilateral and/or MHO Quadrilateral Quadrilateral and/or MHO

Power swing detection (ANSI 68, 68T)

Functions 3
Auto-reclosure (ANSI 79)

Synchro-check (ANSI 25)

Breaker failure protection (ANSI 50BF)

Parallel line compensation
1) 1) 1) 1)
Over-/undervoltage protection (ANSI 27, 59) Over-/underfrequency protection (ANSI 81)

Functions 4
Direction ground(earth)-fault protection, grounded (earthed) networks (ANSI 50N, 51N, 67N)

Measured values, extended Min, max, mean

Order No.

Order code

7SA522 - -

C E F H K M N Q

A B C D E F G H J K L M N P Q R
0 1 4 5

1) Only with position 7 of Order No. = 1 or 5.

6/62 Siemens SIP · Edition No. 8

Accessories

Distance Protection 7SA522
Selection and ordering data

Description

Order No.

Connecting cable (copper)

Cable between PC/notebook (9-pin connector) and protection

unit (9-pin connector) (contained in DIGSI 4, but can be

ordered additionally)

7XV5100-4

Voltage transformer miniature circuit-breaker

Rated current 1.6 A; thermal overload release 1.6 A;

overcurrent trip 6 A

3RV1611-1AG14

Manual for 7SA522 English, V4.61 and higher

C53000-G1176-C155-5

German, V4.70

C53000-G1100-C155-8

15
Siemens SIP · Edition No. 8 6/63

Distance Protection 7SA522
Selection and ordering data

Accessories
1 2 3 4 5 6

Description

Order No.

Opto-electric communication converters Optical to X21/RS422 or G703.1 Optical to pilot wires

7XV5662-0AA00 7XV5662-0AC00

Additional interface modules Protection data interface FO5, OMA1, 820 nm, multi-mode FO cable, ST connector, 1.5 km
Protection data interface FO6, OMA2, 820 nm, multi-mode FO cable, ST connector, 3.5 km
Protection data interface FO17, 1300 nm, mono-mode FO cable, LC-Duplex connector, 25 km
Protection data interface FO18, 1300 nm, mono-mode FO cable, LC-Duplex connector, 60 km
Protection data interface FO19, 1550 nm, mono-mode FO cable, LC-Duplex connector, 100 km

C53207-A351-D651-1 C53207-A351-D652-1 C53207-A351-D655-1 C53207-A351-D656-1 C53207-A351-D657-1

Optical repeaters
Serial repeater (2-channel), opt. 1300 nm, mono-mode FO cable, LC-Duplex connector, 25 km
Serial repeater (2-channel), opt. 1300 nm, mono-mode FO cable, LC-Duplex connector, 60 km
Serial repeater (2-channel), opt. 1550 nm, mono-mode FO cable, LC-Duplex connector, 100 km

7XV5461-0BG00 7XV5461-0BH00 7XV5461-0BJ00

9 10 11 12 13 14 15

LSP2289-afp.eps

Accessories
Fig. 6/75 Mounting rail for 19" rack

LSP2091-afp.eps

LSP2090-afp.eps

Fig. 6/76 2-pin connector

Fig. 6/77 3-pin connector

LSP2092-afp.eps

LSP2093-afp.eps

Fig. 6/78 Short-circuit link for current contacts

Fig. 6/79 Short-circuit link for voltage contacts/ indications contacts

Description

Order No.

Connector

2-pin 3-pin

C73334-A1-C35-1 C73334-A1-C36-1

Crimp connector
Crimping tool

CI2 0.5 to 1 mm2

0-827039-1 0-827396-1

CI2 0.5 to 2.5 mm2

0-827040-1 0-827397-1

Type III+ 0.75 to 1.5 mm2 0-163083-7 0-163084-2

For type III+ and matching female For CI2 and matching female

0-539635-1 0-539668-2 0-734372-1 1-734387-1

19"-mounting rail

C73165-A63-D200-1

Short-circuit For current terminals

links

For other terminals

C73334-A1-C33-1 C73334-A1-C34-1

Safety cover large for terminals small

C73334-A1-C31-1 C73334-A1-C32-1

Size of Supplier Fig. package

Siemens 6/77

Siemens 6/78

4000

Siemens 6/76

Siemens 6/79

Siemens 6/80

Siemens 6/51

1) Your local Siemens representative can inform you on local suppliers.

6/64 Siemens SIP · Edition No. 8.1

Distance Protection 7SA522
Connection diagram, IEC

Fig. 6/80 Housing 1/2 x 19", basic version 7SA522x-xA, 7SA522x-xE and 7SA522x-xJ with 8 binary inputs and 16 binary outputs, hardware version .../FF

Fig. 6/81a

Additional setting by jumpers: Separation of common circuit of BO8 to BO12 with jumpers X80, X81, X82. Switching of BO13, BO14, BO15 as NO contact or NC contact with jumpers.

Fig. 6/81 Serial interfaces

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 6/65

Distance Protection 7SA522
Connection diagram, IEC

Fig. 6/83a Additional setting by jumpers:

Separation of common circuit

of BO8 to BO12 with jumpers

X80, X81, X82. Switching

of BO13, BO14, BO15 as NO contact or NC contact with

jumpers.

1) High-speed trip outputs in versions 7SA522x-xN, 7SA522x-xQ, 7SA522x-xS. Note: For serial interfaces see Figure 6/82.

Fig. 6/82 Housing x 19",medium version 7SA522x-xC, 7SA522x-xG, 7SA522x-xL, 7SA522x-xN, 7SA522x-xQ and 7SA522x-xS with 16 binary inputs and 24 binary outputs, hardware version .../FF

6/66 Siemens SIP · Edition No. 8

Distance Protection 7SA522
Connection diagram, IEC

Fig. 6/84a Additional setting by jumpers:

Separation of common circuit

of BO8 to BO12 with jumpers

X80, X81, X82. Switching

of BO13, BO14, BO15 as NO contact or NC contact with

jumpers.

1) High-speed trip outputs in versions 7SA522x-xP, 7SA522x-xR, 7SA522x-xT.
Note: For serial interfaces see Figure 6/82.
Fig. 6/83 Housing x 19", maximum version 7SA522x-xD, 7SA522x-xH, 7SA522x-xM, 7SA522x-xP, 7SA522x-xR and 7SA522x-xT with 24 binary inputs and 32 binary outputs, hardware version .../FF

13 14 15

Siemens SIP · Edition No. 8 6/67

Distance Protection 7SA522
Connection diagram, ANSI

Fig. 6/85a Additional setting by jumpers:

Separation of common circuit

of BO8 to BO12 with jumpers

X80, X81, X82. Switching

of BO13, BO14, BO15 as NO contact or NC contact with

jumpers.

Note: For serial interfaces see Figure 6/82.

Fig. 6/84 Housing ½ x 19", basic version 7SA522x-xA, 7SA522x-xE and 7SA522x-xJ with 8 binary inputs and 16 binary outputs, hardware version .../FF

6/68 Siemens SIP · Edition No. 8

Distance Protection 7SA522
Connection diagram, ANSI

Fig. 6/86a Additional setting by jumpers:

Separation of common circuit

of BO8 to BO12 with jumpers

X80, X81, X82. Switching

of BO13, BO14, BO15 as NO contact or NC contact with

jumpers.

1) High-speed trip outputs in versions 7SA522x-xN, 7SA522x-xQ, 7SA522x-xS. Note: For serial interfaces see Figure 6/82.
Fig. 6/85 Housing x 19",medium version 7SA522x-xC, 7SA522x-xG, 7SA522x-xL, 7SA522x-xN, 7SA522x-xQ and 7SA522x-xS with 16 binary inputs and 24 binary outputs, hardware version .../FF

14 15
Siemens SIP · Edition No. 8 6/69

Distance Protection 7SA522
Connection diagram, ANSI

Fig. 6/87a Additional setting by jumpers:

Separation of common circuit

of BO8 to BO12 with jumpers

X80, X81, X82. Switching

of BO13, BO14, BO15 as NO contact or NC contact with

jumpers.

13 14

1) High-speed trip outputs in versions 7SA522x-xP, 7SA522x-xR, 7SA522x-xT.
Note: For serial interfaces see Figure 6/82.

Fig. 6/86 Housing x 19", maximum version 7SA522x-xD, 7SA522x-xH and 7SA522x-xM with 24 binary inputs and 32 binary outputs, hardware version ../FF

6/70 Siemens SIP · Edition No. 8

Line Differential Protection

Page

SIPROTEC 7SD61 differential protection relay for two line ends
SIPROTEC 7SD52/53 multi-end differential and distance protection in one relay

7/3 7/25

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
7/2 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD61
SIPROTEC 7SD61 differential protection relay for two line ends

Function overview

Fig. 7/1 SIPROTEC 7SD61 differential protection relay

LSP2247-afpen.tif

Protection functions ·Differential protection for universal use with power lines and
cables on all voltage levels with phase-segregated measurement (87L) ·Two line ends capability ·Suitable for transformers in protected zones (87T) ·Restricted ground-fault protection (87N) if a transformer is within the protection zone ·Well-suited for serial compensated lines ·Two independent differential stages: one stage for sensitive measuring for high-resistance faults and one stage for high-current faults and fast fault clearance ·Breaker-failure protection (50BF) ·Phase and ground overcurrent protection with directional element (50, 50N, 51, 51N, 67, 67N) ·Phase-selective intertripping (85) ·Overload protection (49) ·Over/undervoltage protection (59/27) ·Over/underfrequency protection (81O/U) ·Auto-reclosure single/three-pole (79)

Description
The 7SD610 relay is a differential protection relay suitable for all types of applications and incorporating all those functions required for differential protection of lines, cables and transformers. Transformers and compensation coils within the differential protection zone are protected by means of integrated functions, which were previously to be found only in transformer differential protection. It is also well-suited for complex applications such as series and parallel compensation of lines and cables.
It is designed to provide differential and directional back-up protection for all voltage levels and types of networks. The relay features high speed and phase-selective short-circuit measurement. The unit is thus suitable for single-phase and three-phase fault clearance.
Digital data communication for differential current measurement is effected via fiber-optic cables, networks or pilot wires connections, so that the line ends can be quite far apart. The serial protection interface (R2R interface) of the relay can flexibly be adapted to the requirements of all existing communication media. If the communication method is changed, flexible retrofitting of communication modules to the existing configuration is possible.
Apart from the main protection function, i.e. the differential protection, the 7SD610 has a full range of configurable emergency and / or back-up protection functions such as phase and ground overcurrent protection with directional elements if voltage transformers are connected. Overload, under- and over-voltage/ frequency and breaker-failure protection round off the functional scope of the 7SD610.

Control functions ·Command and inputs for control of CB and disconnectors
(isolators)
Monitoring functions ·Self-supervision of the relay ·Trip circuit supervision (74TC) ·8 oscillographic fault records ·CT-secondary current supervision ·Event logging / fault logging ·Switching statistics
Front design ·User-friendly local operation ·PC front port for convenient relay setting ·Function keys and 8 LEDs for local alarm
Communication interfaces ·1 serial protection data (R2R) interface ·Front interface for PC connection ·System interface
IEC 61850 Ethernet IEC 60870-5-103 protocol PROFIBUS DP, DNP 3 and MODBUS ·Service / modem interface (rear) ·Time synchronization via IRIG-B, DCF77 or system interface
Features ·Browser-based commissioning tool ·Direct connection to digital communication networks

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 7/3

Line Differential Protection / 7SD61
Application

Fig. 7/2

7 8 9 10 11 12 13 14 15

Application
The 7SD610 relay is a differential protection relay suitable for all types of applications and incorporating all those functions required for differential protection of lines, cables and transformers. Transformers and compensation coils within the differential protection zone are protected by means of integrated functions, which were previously to be found only in transformer differential protection. It is also well-suited for complex applications such as series and parallel compensation of lines and cables.
It is designed to provide protection for all voltage levels and types of networks; two line ends may lie within the protection zone. The relay features very high-speed and phase-selective short-circuit measurement. The unit is thus suitable for single and three-phase fault clearance. The necessary restraint current for secure operation is calculated from the current transformer data by the differential protection unit itself.
Digital data communication for differential current measurement is effected via fiber-optic cables, digital communication networks or pilot wires, so that the line ends can be quite far apart. Thanks to special product characteristics, the relay is particularly suitable for use in conjunction with digital communication networks.
The units measure the delay time in the communication network and adaptively match their measurements accordingly. The units can be operated through pilot wires or twisted telephone pairs at typical distances of 8 km by means of special converters.
The serial communication interfaces for data transmission between the ends are replaceable by virtue of plug-in modules and can easily be adapted to multi-mode and mono-mode fiber-optic cables and to leased lines within the communication networks. Secure, selective and sensitive protection of two-end lines can now be provided by means of these relays.

ANSI 87L 87T 87N 85 86 50/50N 51/51N/67/67N 50HS
79
49 50BF 59/27 81O/U 74TC

Protection functions I for lines / cables
I for lines / cables with transformers Restricted ground-fault protection Phase-selective intertrip, remote trip
Lockout function
Overcurrent protection with directional elements
Instantaneous high-current tripping (switch-onto-fault) Single or three-pole auto-reclosure with new adaptive technology Overload protection
Breaker-failure protection Overvoltage / undervoltage protection Overfrequency / underfrequency protection Trip circuit supervision

7/4 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD61
Application

Typical applications employing fiberoptic cables or communication networks
Five applications are shown in Fig. 7/3. The 7SD610 differential protection relay is connected to the current transformers and to the voltage transformers at one end of the cable, although only the currents are required for the differential protection function. The voltage connection improves, among other things, the frequency measurement and allows the measured values and the fault records to be extended. Direct connection to the other units is effected via mono-mode fiber-optic cables and is thus immune to interference.
Five different modules are available. In the case of direct connection via fiber-optic cables, data communication is effected at 512 kbit/s and the command time of the protection unit is reduced to 15 ms. Parallel compensation (for the load currents) is provided within the protection zone of the cable. By means of the integrated inrush restraint, the differential protection relay can tolerate the surge on switching-on of the cable and the compensation reactors, and thus allows sensitive settings to be used under load conditions.
7SD610 offers many features to reliably and safely handle data exchange via communication networks.
Depending on the bandwidth available a communication converter for G70364 kbit/s or X21-64/128/512 kbit/s can be selected. For higher communication speed a communication converter with G703-E1 (2,048 kbit/s) or G703-T1 (1,554 kbit/s) is available. Furthermore the 7SD610 supports the IEEE C37.94 interface with 1/2/4 and 8 timeslots.
The connection to the communication converter is effected via a cost-effective 820 nm interface with multi-mode fiber. This communication converter converts the optical input to electrical signals in accordance to the specified telecommunication interface.
The fourth example shows the relays being connected via a twisted pilot pair. Data exchange and transmission is effected via pilot wires of a typical length of 15 km. Here a transformer is in the protected zone. In this application, 7SD610 is set like a transformer differential relay. Vector group matching and inrush restraint is provided by the relay.

max. 1.5 km with 62.5 m/125 m multi-mode fiber

IEEE C37.94

MUX

Communication network

max. 1.5 km with 62.5 m/125 m multi-mode fiber

MUX

IEEE C37.94

FO30 with ST connectors

Fig. 7/3 Typical applications

SIPV6.010en.eps

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 7/5

Line Differential Protection / 7SD61
Construction, protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Fig. 7/4
Construction
The 7SD610 is available in a housing width of 1/3, referred to a 19" module frame system. The height is a uniform 245 mm for flush-mounting housings and 266 mm for surface-mounting housings.
All cables can be connected with or without cable ring lugs. Plug-in terminals are available as an option, it is thus possible to employ prefabricated cable harnesses. In the case of surface mounting on a panel, the connection terminals are located above and below in the form of screw-type terminals. The communication interfaces are located on the same sides of the housing. For dimensions, please refer to "Dimension drawings".
Protection functions
Differential protection (ANSI 87L, 87T, 87N)
The differential protection function has the following features: ·Measurements are performed separately for each phase; thus
the trip sensitivity is independent of the fault type. ·An adaptive measurement method with high sensitivity for
differential fault currents below the rated current offers the detection of highly resistive faults. This trip element uses special filters, which offer high security even with high level DC components in the short-circuit current. The trip time of this stage is about 35 ms, the pickup value is about 10 % of the rated current. ·A high-set differential trip stage which clears differential fault currents higher than the rated current within 15 ms offers fast tripping time and high-speed fault clearance time. A high-speed charging comparison method is employed for this function. ·When a long line or cable is switched on at one end, transient peaks of the charge current load the line. To avoid a higher setting of the sensitive differential trip stage, this setpoint may be increased for a settable time. This offers greater sensitivity under normal load conditions.

LSP2236-afpen.tif

·A special feature of the unit is parameterization of the current transformer data. The unit automatically calculates the necessary restraint current by means of the previously entered current transformer error. The unit thus adaptively matches the working point on the tripping characteristic so that it is no longer necessary for the user to enter characteristic settings.
·Different current-transformer ratios may be employed at the ends of the line. A mismatch of 1: 8 is permissible.
·Differential protection tripping can be guarded with overcurrent pickup. In this case, pickup of the protection relay is initiated only on simultaneous presence of differential current and overcurrent.
·Easy to set tripping characteristic. Because the relay works adaptively, only the set-point IDiff> (sensitive stage) and IDiff>> (high-set current differential stage) must be set according to the charge current of the line/cable.
·Differential and restraint current are monitored continuously during normal operation and are displayed as operational measured values.
·High stability during external faults even with different current transformers saturation level. For an external fault, only 5 ms of saturation-free time are necessary to guarantee the stability of the differential protection.
·Single-phase short-circuits within the protection zone can be cleared using a time delay, whereas multi-phase faults are cleared instantaneously. Because of this function, the unit is optimally suited for applications in inductively compensated networks, where differential current can occur as a result of charge transfer phenomena on occurrence of a single-phase ground fault within the protection zone, thus resulting in undesired tripping by the differential protection relay. Undesired tripping of the differential protection can be suppressed by making use of the provision for introduction of a time delay on occurrence of single-phase faults.
·With transformers or compensation coils in the protection zone, the sensitive response threshold IDiff> can be blocked by an inrush detection function. Like in transformer differential protection, it works with the second harmonic of the measured current compared with the fundamental component. Blocking is cancelled when an adjustable threshold value of the shortcircuit current is reached, so that very high current faults are switched off instantaneously.
·In the case of transformers within the protection zone, vector group adaptation and matching of different current transformer ratios is carried out within the unit. The interference zero current, which flows through the grounded winding, is eliminated from the differential current measurement. The 7SD610 thus behaves like a transformer differential relay whose ends, however, can be quite far apart.
·A more sensitive protection for transformers within the protection zone is given by measurement of the star-point current on an grounded winding. Therefore the IE current measurement input has to be used. If the sum of the phase currents of a winding is compared with the measured star-point current, a sensitive ground-current differential protection (REF) can be implemented. This function is substantially more sensitive than the differential protection during faults to ground in a winding, detecting fault currents as small as 10 % of the transformer rated current.

7/6 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD61
Protection functions

Characteristics of differential protection communciation through the remote relay interfaces

The 7SD610 is ideally adapted for application in communication networks.

The data required for measurement of differential currents and numerous other variables are exchanged between the protection units in the form of synchronous serial telegrams employing the full duplex mode. The telegrams are secured using 32-bit check-sums so that transmission errors in a communication network are detected immediately. Moreover, each telegram carries a time stamp accurate to a microsecond, thus allowing measurement and monitoring of the continuous transmission delay times.
·Data communication is immune to electromagnetic interference, since fiber-optic cables are employed in the critical region, e.g. in the relay house or relay room.
·Monitoring of each individual incoming telegram and of overall communication between the units, no need of supplementary equipment. The check sum (correctness of the telegram contents), the address of the neighboring unit and the transmission delay time of the telegram are monitored.
·Unambiguous identification of each unit is ensured by assignment of a settable communication address within a differential protection topology. Only those units mutually known to each other can cooperate. Incorrect interconnection of the communication links results in blocking of the protection system.
·Detection of telegrams, which are reflected back to the transmitting unit within the communication network.
·Detection of path switching in a communication network. Automatic restraint of the protection function until measurement of the parameters of the new communication link has been completed.
·Continuous measurement of the transmission delay time to the remote line end. Taking into account the delay time in differential current measurement and compensation thereof, including monitoring of a settable maximum permissible delay time of 30 ms.
·Generation of alarm signals on disturbed communication links. Statistical values for the percentage availability of the communication links per minute and per hour are available as operational measured values.
·With a GPS high-precision 1-s pulse from a GPS receiver the relays can be syncronized with an absolute, exact time at each line end. In this way, the delay in the receive and transmit path can be measured exactly. With this optional feature the relay can used in communication networks where this delay times are quite different.
Phase-selective intertrip and remote trip/indications
Normally the differential current is calculated for each line end nearly at the same time. This leads to fast and uniform tripping times. Under weak infeed conditions, especially when the differential function is combined with an overcurrent pickup, a phase-selective intertrip offers a tripping of both line ends.
·7SD610 has 4 intertrip signals which are transmitted in highspeed mode (20 ms) to the other terminals. These intertrip signals can also be initiated and transmitted by an external relay via binary inputs. In cases where these signals are not employed for breaker intertripping, other alternative information can be rapidly transmitted to the remote end of the line.

Fig. 7/5 Tripping characteristic
·In addition, four high-speed remote commands are available, which can be introduced either via a binary input or by means of an internal event and then rapidly communicated to the other end.
·Provided that the circuit-breaker auxiliary contacts are wired to binary inputs at the line ends, the switching status of the circuit-breakers is indicated and evaluated at the remote ends of the line. Otherwise the switching status is derived from the measured current.
Possible modes of operation of the differential protection section
Special modes of operation such as the "Commissioning mode" and "Test operation" are advantageous for commissioning and servicing the units.
·In general, an alarm indication is generated on interruption of the communication links and an attempt is made to re-establish the communication link. The units operate in the emergency mode, provided that these have been parameterized.
·The complete configuration can also be used in a testing mode. The local end is in an operating mode, which, for example, allows the pickup values to be tested. The current values received from the remote end of the line are set to zero, so as to achieve defined test conditions. The remote-end unit ignores the differential currents, which occur as a result of testing, and blocks differential protection and breaker intertripping. It may optionally operate in the backup protection mode.
·Differential protection is activated in the commissioning mode. However, test currents injected at one end of the line and which generate a differential current do not lead to output of a TRIP command by the differential protection or to breaker intertripping. All those indications that would actually occur in conjunction with a genuine short-circuit are generated and displayed. TRIP commands can be issued by the backup protection.

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 7/7

Line Differential Protection / 7SD61
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Thermal overload protection (ANSI 49)
A built-in overload protection with a current and thermal alarm stage is provided for thermal protection of cables and transformers.
The trip time characteristics are exponential functions according to IEC 60255-8. The preload is considered in the trip times for overloads.
An adjustable alarm stage can initiate an alarm before tripping is initiated.

Overcurrent protection (ANSI 50, 50N, 51, 51N, 67, 67N)
The 7SD610 provides a three-stage overcurrent protection. Two definite-time stages and one inverse-time stage (IDMT) are available, separately for phase currents and for the ground current. Two operating modes (backup, emergency) are selectable. Two stages e.g. can run in backup mode, whereas the third stage is configured for emergency operation, e.g. during interruption of the protection communication and/or failure of the voltage in the VT secondary circuit. The secondary voltage failure can be detected by the integrated fuse failure monitor or via a binary input from a VT miniature circuit-breaker (VT m.c.b. trip).
The following ANSI/IEC inverse-time characteristics are available:
·Inverse
·Short inverse
·Long inverse
·Moderately inverse
·Very inverse
·Extremely inverse
·Definite inverse
If VTs are connected, separate stages with directional measurement are available, two definite-time and two inverse-time stages (each for phase and ground). Using the forward pickup indication as a signal to the remote end, a 100 % protection coverage of the line can be operated in parallel to the differential protection.
Instantaneous high-speed switch-onto-fault overcurrent protection (ANSI 50HS)
Instantaneous tripping is possible when energizing a faulty line. On large fault currents, the high-speed switch-onto-fault overcurrent stage can initiate very fast three-pole tripping.
Circuit-breaker closure onto a faulty line is also possible provided that the circuit-breaker auxiliary contacts of the remote end are connected and monitored. If an overcurrent arises on closing of the circuit-breaker at one end of a line (while the other end is energized) the measured current can only be due to a short-circuit. In this case, the energizing line end is tripped instantaneously.
In the case of circuit-breaker closure, the auto-reclosure is blocked at both ends of the line to prevent a further unsuccessful closure onto a short-circuit. If circuit-breaker intertripping to the remote end is activated, intertripping is also blocked.

Fig. 7/6 Inverse

0,14

( ) t =

0,02

I / Ip -1

Auto-reclosure (ANSI 79)
The 7SD610 relay is equipped with an auto-reclose function (AR). The function includes several operating modes:
·3-pole auto-reclosure for all types of faults; different dead times are available depending the type of fault
·1-pole auto-reclosure for 1-phase faults, no reclosing for multiphase faults
·1-pole auto-reclosure for 1-phase faults and for 2-phase faults without ground, no reclosing for multi-phase faults
·1-pole auto-reclosure for 1-phase and 3-pole auto-reclosing for multi-phase faults
·1-pole auto-reclosure for 1-phase faults and 2-phase faults without ground and 3-pole auto-reclosure for other faults
·Multiple-shot auto-reclosure
·Interaction with an external device for auto-reclosure via binary inputs and outputs
·Control of the integrated AR function by external protection
·Adaptive auto-reclosure. Only one line end is closed after the dead time. If the fault persists this line end is switched off. Otherwise the other line ends are closed via a command over the communication links. This avoids stress when heavy fault currents are fed from all line ends again.
·Interaction with an external synchro-check
·Monitoring of the circuit-breaker auxiliary contacts

15
7/8 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD61
Protection functions

In addition to the above-mentioned operating modes, several other operating principles can be employed by means of the integrated programmable logic (CFC).
Integration of auto-reclosure in the feeder protection allows evaluation of the line-side voltages. A number of voltagedependent supplementary functions are thus available:
·DLC By means of dead-line check, reclosure is effected only when the line is deenergized (prevention of asynchronous breaker closure).
·ADT The adaptive dead time is employed only if auto-reclosure at the remote station was successful (reduction of stress on equipment).
·RDT Reduced dead time is employed in conjunction with autoreclosure where no tele-protection method is employed: When faults within the zone extension, but external to the protected line, are switched off for rapid auto-reclosure (RAR), the RDT function decides on the basis of measurement of the return voltage from the remote station which has not tripped whether or not to reduce the dead time.

The 7SD610 is fitted, in addition, with three two-stage undervoltage measuring elements: ·Phase-to-ground undervoltage ·Phase-to-phase undervoltage ·Positive-sequence undervoltage
The undervoltage measuring elements can be blocked by means of a minimum current criterion and by means of binary inputs.
Frequency protection (ANSI 81O/U)
Frequency protection can be used for overfrequency and underfrequency protection. Unwanted frequency changes in the network can be detected and the load can be removed at a specified frequency setting. Frequency protection can be used over a wide frequency range (45 to 55, 55 to 65 Hz). There are four elements (selectable as overfrequency or underfrequency) and each element can be delayed separately.

Breaker failure protection (ANSI 50BF)
The 7SD610 relay incorporates a two-stage breaker failure protection to detect the failure of tripping command execution, for example, due to a defective circuit-breaker. The current detection logic is phase-segregated and can therefore also be used in single-pole tripping schemes. If the fault current is not interrupted after a settable time delay has expired, a retrip command or a busbar trip command is generated. The breaker failure protection can be initiated by all integrated protection functions as well as by external devices via binary input signals.

Overvoltage protection, undervoltage protection (ANSI 59, 27)
A voltage rise can occur on long lines that are operating at noload or are only lightly loaded. The 7SD610 contains a number of overvoltage measuring elements. Each measuring element is of two-stage design. The following measuring elements are available:
·Phase-to-ground overvoltage
·Phase-to-phase overvoltage
·Zero-sequence overvoltage ·The zero-sequence voltage can be connected to the 4th voltage
input or be derived from the phase voltages.
·Positive-sequence overvoltage of the local end or calculated for the remote end of the line (compounding).
·Negative-sequence overvoltage
Tripping by the overvoltage measuring elements can be effected either at the local circuit-breaker or at the remote station by means of a transmitted signal.

1 2 3 4 5 6 7 8 9 10 11 12 13

15
Siemens SIP · Edition No. 8 7/9

Line Differential Protection / 7SD61
Protection functions

Monitoring and supervision functions

Lockout (ANSI 86)

The 7SD610 relay provides comprehensive monitoring functions All binary outputs can be stored like LEDs and reset using the

covering both hardware and software. Furthermore, the mea-

LED reset key. The lockout state is also stored in the event of

sured values are continuously checked for plausibility. Therefore supply voltage failure. Reclosure can only be issued after the

the current and voltage transformers are also included in this

lockout state is reset.

monitoring system.

Local measured values

Current transformer / Monitoring functions

The measured values are calculated from the measured current

A broken wire between the CTs and relay inputs under load may and voltage signals along with the power factor (cos ), the

lead to malopera- tion of a differential relay if the load current

frequency, the active and reactive power. Measured values are

exceeds the differential setpoint. The 7SD610 provides fast bro- displayed as primary or secondary values or in percent of the

ken wire supervision which immediatelly blocks all line ends if

specific line rated current and voltage. The relay uses a 20 bit

a broken wire condition is measured by a local relay. This avoids high-resolution AD converter and the analog inputs are factory-

maloperation due to broken wire condition. Only the phase

calibrated, so a high accuracy is reached.

where the broken wire is detected is blocked. The other phases remain under differential operation.

The following values are available for measured-value processing:

Fuse failure monitoring

·Currents 3 x IPhase, 3I0, IE, IE sensitive

If any measured voltage is not present due to short-circuit or

·Voltages 3 x VPhase-Ground, 3 x VPhase-Phase,

open circuit in the voltage transformer secondary circuit this can ·3V0,Ven,

lead to a failure or a being missing measuring of the directional ·Symmetrical components I1, I2, V1, V2

overcurrent protection. This secondary voltage interruption can be detected by means of the integrated fuse failure monitor. Immediate blocking of the directional steps of the overcurrent

·Real power P (Watt), reactive power ·Q (Var), apparent power S (VA)

protection is started automatically.

·Power factor PF (= cos )

Additional measurement supervision functions are

·Symmetry of voltages and currents

·Frequency f ·Differential and restraint current per phase

·Summation of currents and voltages

·Availability of the data connection to the remote line ends per minute and per hour

Trip circuit supervision (ANSI 74TC)

One or two binary inputs for each circuit- breaker pole can be

used for monitoring the circuit-breaker trip coils including the

·Regarding delay time measuring with the GPS-version the absolute time for transmit and receive path is displayed separately.

connecting cables. An alarm signal is issued whenever the circuit Limit value monitoring: Limit values are monitored by means

is interrupted.

of the CFC. Commands can be derived from these limit value indications.

15
7/10 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD61
Protection functions

Measured values at remote line ends
Every two seconds the currents and voltages are freezed at the same time at all line ends and transmitted via the communication link. At a local line end, currents and voltages are thus available with their amount and phases (angle) locally and remotely. This allows checking the whole configuration under load conditions. In addition, the differential and restraint currents are also displayed. Important communication measurements, such as delay time or faulty telegrams per minute/ hour are also available as measurements. These measured values can be processed with the help of the CFC logic editor.

Commissioning
Special attention has been paid to commissioning. All binary inputs and outputs can be displayed and activated directly. This can simplify the wiring check significantly for the user. The operational and fault events and the fault records are clearly arranged.
Furthermore, all currents and optional voltages and phases are available via communication link at the local relay and are displayed in the relay, with DIGSI 4 or with the Web Monitor.
The operational and fault events and fault records from all line ends share a common time tagging which allows to compare events registered in the different line ends on a common time base.

Fig. 7/7 Browser-aided commissioning: Phasor diagram

WEB Monitor Internet technology simplifies visualization

In addition to the universal DIGSI 4 operating program, the relay contains a WEB server that can be accessed via a telecommunication link using a browser (e.g. Internet Explorer). The advantage of this solution is to operate the unit with standard software tools and at the same time make use of the Intranet/Internet infrastructure. This program shows the protection topology and comprehensive measurements from local and remote line ends. Local and remote measurements are shown as phasors and the breaker positions of each line end are depicted. It is possible to check the correct connection of the current transformers or the correct vector group of a transformer.

Fig. 7/8 Browser-aided commissioning: Differential protection tripping characteristic

Stability can be checked by using the operating characteristic as well as the calculated differential and restraint values in the browser windows.

Event log and trip log messages are also available. Remote control can be used, if the local front panel cannot be accessed.

LSP2846.tif

LSP2845.tif

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 7/11

Line Differential Protection / 7SD61
Functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Functions
Control and automation functions
Control
In addition to the protection functions, the SIPROTEC 4 units also support all control and monitoring functions that are required for operating medium-voltage or high-voltage substations.
The main application is reliable control of switching and other processes.
The status of primary equipment or auxiliary devices can be obtained from auxiliary contacts and communicated via binary inputs. Therefore it is possible to detect and indicate both the OPEN and CLOSED position or a fault or intermediate circuitbreaker or auxiliary contact position.
The switchgear or circuit-breaker can be controlled via: integrated operator panel binary inputs substation control and protection system DIGSI 4
Command processing
All the functionality of command processing is offered. This includes the processing of single and double commands with or without feedback, sophisticated monitoring of the control hardware and software, checking of the external process, control actions using functions such as runtime monitoring and automatic command termination after output. Here are some typical applications: ·Single and double commands using 1, 1 plus 1 common or 2
trip contacts ·User-definable bay interlocks ·Operating sequences combining several switching operations
such as control of circuit-breakers, disconnectors and grounding switches ·Triggering of switching operations, indications or alarm by combination with existing information

Assignment of feedback to command
The positions of the circuit-breaker or switching devices and transformer taps are acquired by feedback. These indication inputs are logically assigned to the corresponding command outputs. The unit can therefore distinguish whether the indication change is a consequence of switching operation or whether it is a spontaneous change of state (intermediate position).
Chatter disable
The chatter disable feature evaluates whether, in a configured period of time, the number of status changes of indication input exceeds a specified figure. If exceeded, the indication input is blocked for a certain period, so that the event list will not record excessive operations.
Filter time
All binary indications can be subjected to a filter time (indication suppression).
Indication filtering and delay
Indications can be filtered or delayed.
Filtering serves to suppress brief changes in potential at the indication input. The indication is passed on only if the indication voltage is still present after a set period of time. In the event of indication delay, there is a wait for a preset time. The information is passed on only if the indication voltage is still present after this time.
Indication derivation
A further indication (or a command) can be derived from an existing indication. Group indications can also be formed. The volume of information to the system interface can thus be reduced and restricted to the most important signals.
Transmission lockout
A data transmission lockout can be activated, so as to prevent transfer of information to the control center during work on a circuit bay.

Test operation
During commissioning, all indications can be passed to an automatic control system for test purposes.

Switching authority
Switching authority is determined according to parameters, communication or by key-operated switch (when available).
If a source is set to "LOCAL", only local switching operations are possible. The following sequence of switching authority is laid down: "LOCAL"; DIGSI PC program, "REMOTE"
Every switching operation and change of breaker position is kept in the status indication memory. The switch command source, switching device, cause (i.e. spontaneous change or command) and result of a switching operation are retained.

15
7/12 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD61
Functions

With respect to communication, particular emphasis has been

placed on high flexibility, data security and use of customary standards in the field of energy automation. The concept of the

communication modules allows interchangeability on the one

hand, and, on the other hand, is open for future standards.

Local PC interface

The PC interface provided on the front panel on the unit allows

the parameters, status and fault event data to be rapidly accessed

by means of the DIGSI 4 operating program. Use of this program

is particularly advantageous during testing and commissioning.

Rear-mounted interfaces

The service and system communication interfaces are located at

the rear of the unit. In addition, the 7SD610 is provided with a

protection interface. The interface complement is variable and

retrofitting is possible without any difficulty. These interfaces ensure that the requirements for different communication

Fig. 7/9 IEC 60870-5-103 star-type RS232 copper conductor connection or fiber-optic connection

interfaces (electrical and optical) and protocols can be met.

The interfaces are designed for the following applications:

Service / modem interface

By means of the RS485 interface, it is possible to efficiently oper-

ate a number of protection units centrally via DIGSI 4. Remote

operation is possible on connection of a modem. This offers the

advantage of rapid fault clarification, especially in the case of

unmanned power plants.

In the case of the 7SD610, a PC with a standard browser can

be connected to the service interface (refer to "Commissioning

program").

System interface

This interface is used to carry out communication with a control

or protection and control system and supports a variety of com-

munication protocols and interface designs, depending on the

module connected.

Commissioning aid via a standard Web browser
In the case of the 7SD610, a PC with a standard browser can be connected to the local PC interface or to the service interface (refer to "Commissioning program"). The relays include a small Web server and sends its HTML pages to the browser via an established dial-up network connection.
Retrofitting: Modules for every type of communication
Communication modules for retrofitting are available for the entire SIPROTEC 4 unit range. These ensure that, where different communication interfaces (electrical or optical) and protocols (IEC 61850 Ethernet, IEC 60870-5-103, PROFIBUS DP, DNP 3.0, MODBUS, DIGSI, etc.) are required, such demands can be met.

Fig. 7/10 Bus structure for station bus with Ethernet and IEC 61850
Safe bus architecture ·RS485 bus
With this data transmission via copper conductors, electromagnetic fault influences are largely eliminated by the use of twisted-pair conductor. Upon failure of a unit, the remaining system continues to operate without any disturbances. ·Fiber-optic double ring circuit The fiber-optic double ring circuit is immune to electromagnetic interference. Upon failure of a section between two units, the communication system continues to operate without disturbance.
It is generally impossible to communicate with a unit that has failed. If a unit were to fail, there is no effect on the communication with the rest of the system.

10 11 12 13 14

15
Siemens SIP · Edition No. 8 7/13

Line Differential Protection / 7SD61
Communication

1 2 3 4 5 6 7 8 9 10 11

Communication

IEC 61850 Ethernet
The Ethernet-based IEC 61850 protocol is the worldwide standard for protection and control systems used by power supply corporations. Siemens was the first manufacturer to support this standard. By means of this protocol, information can also be exchanged directly between bay units so as to set up simple masterless systems for bay ans system interlocking. Access to the units via the Ethernet bus is also possible with DIGSI.
IEC 60870-5-103
IEC 60870-5-103 is an internationally standardized protocol for the efficient communication in the protected area. IEC 60870-5-103 is supported by a number of protection device manufacturers and is used worldwide.

Fig. 7/11 RS232/RS485 electrical communication module

LSP2162-afpen.tif

PROFIBUS DP
PROFIBUS DP is an industry-recognized standard for communications and is supported by a number of PLC and protection device manufacturers.

MODBUS RTU
MODBUS RTU is an industry-recognized standard for communications and is supported by a number of PLC and protection device manufacturers.

Fig. 7/13 820 nm fiber-optic communication module

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 2 compliant with DNP 3.0. DNP 3.0 is supported by a number of protection device manufacturers.

LSP2163-afpen.tif

Fig. 7/12 PROFIBUS fiber-optic double ring communication module
Fig. 7/14 Fiber-optic Ethernet communication module for IEC 61850 with integrated Ethernet switch

LSP3.01-0021.tif

LSP2164-afp.tif

14 15
7/14 Siemens SIP · Edition No. 8

Fig. 7/15 System solution: Communications

Line Differential Protection / 7SD61
Communication

System solutions for protection and station control
Together with the SICAM power automation system, SIPROTEC 4 can be used with PROFIBUS DP. Over the low-cost electrical RS485 bus, or interference-free via the optical double ring, the units exchange information with the control system.
Units featuring IEC 60870-5-103 interfaces can be connected to SICAM in parallel via the RS485 bus or radially by fiber-optic link. Through this interface, the system is open for the connection of units of other manufacturers (see Fig. 7/9).
Because of the standardized interfaces, SIPROTEC units can also be integrated into systems of other manufacturers or in SIMATIC. Electrical RS485 or optical interfaces are available. The optimum physical data transfer medium can be chosen thanks to optoelectrical converters. Thus, the RS485 bus allows low-cost wiring in the cubicles and an interference-free optical connection to the master can be established.
For IEC 61850, an interoperable system solution is offered with SICAM PAS. Via the 100 Mbits/s Ethernet bus, the units are linked with PAS electrically or optically to the station PC. The interface is standardized, thus also enabling direct connection of units of other manufacturers to the Ethernet bus. With IEC 61850, however, the units can also be used in other manufacturers' systems (see Fig. 7/10).
Via modem and service interface, the protection engineer has access to the protection devices at all times. This permits remote maintenance and diagnosis (cyclic testing).
Parallel to this, local communication is possible, for example, during a major inspection.
Serial protection interface (R2R interface)
The 7SD610 provides one protection interface to cover two line end applications.
In addition to the differential protection function, other protection functions can use this interface to increase selectivity and sensitivity as well as covering advanced applications.
·Fast phase-selective teleprotection signaling using the directional stages of the overcurrent protection with POTT or PUTT schemes
·Two terminal line applications can be implemented without additional logic
·Interclose command transfer with the auto-reclosure "Adaptive dead time" (ADT) mode
·4 remote signals for fast transfer of binary signals
·Flexible utilization of the communication channels by means of the programmable CFC logic
The protection interfaces have different options to cover new and existing communication infrastructures. ·FO51), OMA12) module:
820 nm fiber-optic interface with clock recovery/ST connectors for direct connection with multi-mode FO cable up to 1.5 km for the connection to a communication converter. ·FO61), OMA22) module: 820 nm fiber-optic interface/ST connectors for direct connection up to 3.5 km with multi-mode FO cable.

New fiber-optic interfaces, series FO1x
FO171): For direct connection up to 24 km3), 1300 nm, for mono-mode fiber 9/125 m, LC-Duplex connector
FO181): For direct connection up to 60 km3), 1300 nm, for mono-mode fiber 9/125 m, LC-Duplex connector
FO191): For direct connection up to 100 km3), 1550 nm, for mono-mode fiber 9/125 m, LC-Duplex connector
FO30: 820 nm fiber-optic interface/ST connectors for direct connection up to 1.5 km and for connections to a IEEE C37.94 multiplexer interface.
The link to a multiplexed communication network is made by separate communication converters (7XV5662). These have a fiber-optic interface with 820 nm and 2 ST connectors to the protection relay. The link to the communication network is optionally an electrical X21/G703-64 kbit/s or G703-E1/-T1 interface. Furthermore the IEEE C37.94 interface is supported by the FO30 module.
For operation via copper wire communication (pilot wires or twisted telephone pair), a modern communication converter for copper cables is available. This operates with both the two-wire and three-wire copper connections which were used by conventional differential protection systems before. The communication converter for copper cables is designed for 5 kV insulation voltage. An additional 20 kV isolation transformer can extend the field of applications of this technique into ranges with higher insulation voltage requirements. The connection via FO cable to the relay is interference-free. With SIPROTEC 4 and the communication converter for copper cables a digital follow-up technique is available for two-wire protection systems (up to 8 km) and all three-wire protection systems using existing copper communication links.
Different communication converters are listed under "Accessories".
Communication data: ·32-bit CRC-check according to CCITT and ITU ·Each protection relay possesses a unique relay address ·Continuous communication link supervision: Individual faulty
data telegrams do not constitute an immediate danger, if they occur only sporadically. The statistical availability, per minute and hour, of the serial protection interface can be displayed. ·Supported network interfaces X21/RS422 with 64 or 128 or 512 kbit/s; or G703-64 kbit/s and G703-E1 (2,048 kbit/s) or G703-T1 (1,554 kbit/s) or IEEE C37.94. ·Max. channel delay time 0.1 ms to 30 ms (in steps of 0.1 ms) ·Protocol HDLC
1) For flush-mounting housing. 2) For surface-mounting housing. 3) For surface-mounting housing the internal FO module
OMA1 will be delivered together with an external repeater.

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 7/15

Line Differential Protection / 7SD61
Communication
Communication possibilities between relays
1

3
Fig. 7/16 Direct optical link up to 1.5 km/3.5 km, 820nm
4

Fig. 7/17 Direct optical link up to 25/60 km with 1300 nm or up to 100 km with 1550 nm

7
Fig. 7/18 Connection to a communication network CC-XG
8

Fig. 7/19 Connection to a communication network CC-2M

9 10 11

7SD52/53 7SD610 FO30
SIPV6.011en.eps

max. 1.5 km with 62.5 m/125 m multi-mode fiber
IEEE C37.94

MUX Communication network

FO30 with ST connectors

Fig. 7/20 Connection to a communication network via IEEE C37.94

Fig. 7/21 Connection to a pilot wire

15
7/16 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD61
Typical connection

Typical connection

Connection of current

and voltage transformers

A typical connection is to the phase CT. The residual cur-

rent at the IE input is formed by summation of the phase currents. This ensures optimum supervision functions for

the current.

Optionally, voltages are measured by means of voltage

transformers and are fed to the unit as a phase-to-ground

voltage. The zero voltage is derived from the summation

voltage by calculation performed in the unit.

As a matter of fact, the 7SD610 unit does not require any voltage transformers for operation of the differential

Fig. 7/22 Typical connection to current transformers

protection.

Alternative current measurement

3 phase current transformers with neutral point in the

line direction, I4 connected to a current transformer in

the neutral point of a grounded (earthed) transformer

for restricted ground-fault protection (REF) or directional

ground (earth)-fault protection.

Fig. 7/23 Typical connection to current transformers with optional voltage inputs

9 10

Fig. 7/24 Connection for transformer with restricted groundfault protection (REF)

Fig. 7/25 Alternative connection of current transformers for measuring neutral current of a grounded (earthed) power transformer

14 15

Siemens SIP · Edition No. 8 7/17

Line Differential Protection / 7SD61
Technical data

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

General unit data

Analog inputs

Rated frequency

50 or 60 Hz (selectable)

Rated current IN
Rated voltage VN
Power consumption in CT circuits with IN = 1 A with IN = 5 A in VT circuits

1 or 5 A (selectable) 80 to 125 V (selectable)
Approx. 0.05 VA Approx. 0.3 VA Approx. 0.1 VA

Thermal overload capacity in CT circuits (for IN = 5 A)
Dynamic (peak value) In VT circuits for highly sensitive ground-fault protection
in VT circuits

IN 100 A for 1 s 30 IN for 10 s 4 IN continuous 250 IN (half sine)
300 A for 1 s 100 A for 10 s 15 A continuous 230 V per phase continuous

Auxiliary voltage

Rated voltages Ranges are settable by means of jumpers

DC 24 to 48 V DC 60 to 125 V 1) DC 110 to 250 V 1) and AC 115 V (50/60 Hz)1)

Permissible tolerance

-20 % to +20 %

Superimposed AC voltage (peak-to-peak)

15 %

Power consumption

Under normal operating conditions Approx. 8 W

During pickup with all

Approx. 18 W

inputs and outputs activated

Bridging time during failure of the

auxiliary voltage

Vaux 110 V

50 ms

Binary inputs

Number

7 (marshallable)

Rated voltage range Pickup threshold

24 to 250 V, bipolar 17 or 73 V (selectable)

Functions are freely assignable

Minimum pickup threshold Ranges are settable by means of DC 17 or 73 V, bipolar jumpers for each binary input

Maximum permissible voltage

DC 300 V

Current consumption, energized Approx. 1.8 mA

Output relay

Command / indication relay

Number

5 (marshallable) 1 alarm contact (not marshallable)

Switching capacity Make Break Break (with resistive load) Break (with L/R 50 ms)
Switching voltage
Permissible total current
LEDs
Number RUN (green) ERROR (red) LED (red), function can be assigned

1000 W/VA 30 VA 40 W 25 W 250 V 30 A for 0.5 seconds 5 A continuous
1 1 7

7/18 Siemens SIP · Edition No. 8

Unit design

Housing 7XP20

For dimensions refer to dimension drawings, part 14

Degree of protection acc. to EN 60529
Surface-mounting housing Flush-mounting housing
front rear for the terminals

IP 51
IP 51 IP 50 IP 20 with terminal cover put on

Weight

Flush-mounting housing

1/3 x 19"

4 kg

Surface-mounting housing

1/3 x 19"

6 kg

Electrical tests

Specification

Standards

EC 60255 (product standards) ANSI/IEEE C37.90.0/.1/.2 UL 508 For further standards see "Individual functions"

Insulation tests

Standards

IEC 60255-5

Voltage test (100 % test) All circuits except for auxiliary supply, binary inputs and communication interfaces

2.5 kV (r.m.s.), 50 / 60 Hz

Auxiliary voltage and binary inputs (100 % test)

DC 3.5 kV

RS485/RS232 rear side communication interfaces and time synchronization interface (100 % test)

500 V (r.m.s.), 50 / 60 Hz

Impulse voltage test (type test) All circuits except for communication interfaces and time synchronization interface, class III

5 kV (peak); 1.2/50 ms; 0.5 J 3 positive and 3 negative impulses at intervals of 5 s

EMC tests for noise immunity; type tests

Standards

IEC 60255-6, IEC 60255-22 (product standards) (type tests) EN 50082-2 (generic standard) DIN 57435 part 303

High frequency test IEC 60255-22-1, class III and VDE 0435 part 303, class III

2.5 kV (peak); 1 MHz; = 15 ms; 400 surges per s; test duration 2 s

Electrostatic discharge IEC 60255-22-2, class IV EN 61000-4-2, class IV
Irradiation with RF field, non-modulated IEC 60255-22-3 (report), class III

8 kV contact discharge; 15 kV air discharge; both polarities; 150 pF; Ri = 330
10 V/m; 27 to 500 MHz

Irradiation with RF field, amplitude-modulated IEC 61000-4-3, class III

10 V/m; 80 to 1000 MHz; 80 % AM; 1 kHz

1) For flush-mounting housing. 2) For surface-mounting housing. 3) For surface-mounting housing the internal FO module OMA1
will be delivered together with an external repeater.

Line Differential Protection / 7SD61
Technical data

Irradiation with RF field, pulse-modulated IEC 61000-4-3/ ENV 50204, class III Fast transients, bursts IEC 60255-22-4 and IEC 61000-4-4, class IV
High-energy surge voltages (SURGE), IEC 61000-4-5 installation, class III Auxiliary supply
Measurement inputs, binary inputs, binary output relays
Line-conducted HF, amplitudemodulated IEC 61000-4-6, class III Magnetic field with power frequency IEC 61000-4-8, class IV; IEC 60255-6 Oscillatory surge withstand capability ANSI/IEEE C37.90.1
Fast transient surge withstand capability ANSI/IEEE C37.90.1

10 V/m; 900 MHz; repetition frequency 200 Hz; duty cycle 50 %
4 kV; 5/50 ns; 5 kHz; burst length = 15 ms; repetition rate 300 ms; both polarities; Ri = 50 ; test duration 1 min Impulse: 1.2/50 s
Common (longitudinal) mode: 2 kV; 12 ; 9 F Differential (transversal) mode: 1 kV; 2 ; 18 F Common (longitudinal) mode: 2 kV; 42 ; 0.5 F Differential (transversal) mode: 1 kV; 42 ; 0.5 F 10 V; 150 kHz to 80 MHz; 80 % AM; 1 kHz
30 A/m continuous; 300 A/m for 3 s; 50 Hz 0.5 mT; 50 Hz
2.5 to 3 kV (peak); 1 to 1.5 MHz damped wave; 50 surges per second, duration 2 s, Ri = 150 to 200 4 to 5 kV; 10/150 ns; 50 impulses per second; both polarities; duration 2 s; Ri = 80 35 V/m; 25 to 1000 MHz

Radiated electromagnetic interference ANSI/IEEE C37.90.2
Damped oscillation IEC 60694, IEC 61000-4-12

2.5 kV (peak value); polarity alternating 100 kHz; 1 MHz; 10 and 50 MHz; Ri = 200

EMC tests for interference emission; type tests

Standard

EN 50081-1 (generic standard)

Conducted interference voltage on lines, only auxiliary voltage IEC-CISPR 22

150 kHz to 30 MHz

Radio interference field strength Limit class B

IEC-CISPR 22

30 to 1000 MHz

Limit class B

Mechanical dynamic tests

Vibration, shock stress and seismic vibration

During operation

Standards

IEC 60255-21 and IEC 60068-2

Vibration IEC 60255-21-1, class 2 IEC 60068-2-6

Sinusoidal 10 to 60 Hz: ± 0.075 mm amplitude; 60 to 150 Hz: 1 g acceleration frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes

Shock IEC 60255-21-2, class 1 IEC 60068-2-27

Half-sinusoidal Acceleration 5 g, duration 11 ms, 3 shocks on each of the 3 axes in both directions

Seismic vibration IEC 60255-21-2, class 1 IEC 60068-3-3

Sinusoidal 1 to 8 Hz: ± 3.5 mm amplitude (horizontal axis), 1 to 8 Hz: ± 1.5 mm amplitude (vertical axis), 8 to 35 Hz: 1 g acceleration (horizontal axis), 8 to 35 Hz: 0.5 g acceleration (vertical axis), frequency sweep 1 octave/min 1 cycle in 3 orthogonal axes

During transport

Standards

IEC 60255-21 and IEC 60068-2

Vibration IEC 60255-21-1, class 2 IEC 60068-2-6

Sinusoidal 5 to 8 Hz: ± 7.5 mm amplitude; 8 to 150 Hz: 2 g acceleration, Frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes

Shock IEC 60255-21-2, class 1 IEC 60068-2-27

Half-sinusoidal Acceleration 15 g, duration 11 ms, 3 shocks on each of the 3 axes in both directions

Continuous shock IEC 60255-21-2, class 1 IEC 60068-2-29

Half-sinusoidal Acceleration 10 g, duration 16 ms, 1000 shocks on each of the 3 axes in both directions

Climatic stress test

Temperatures

Type-tested acc. to IEC 60068-2-1 25 °C to +85 °C / 13 °F to +185 °F and -2, test Bd, for 16 h

Temporarily permissible operating 20 °C to +70 °C / 4 °F to +158 °F temperature, tested for 96 h

Recommended permanent

5 °C to +55 °C / +25 °F to +131 °F

operating temperature acc. to

IEC 60255-6

(Legibility of display may be

impaired above +55 °C / +131 °C)

Limiting temperature during permanent storage
Limiting temperature during transport

25 °C to +55 °C / 13 °F to +131 °F 25 °C to +70 °C / 13 °F to +158 °F

Humidity

Permissible humidity stress; It Annual average 75 % relative is recommended to arrange the humidity; on 56 days in the year up units in such a way that they are to 93 % relative humidity; moisture not exposed to direct sunlight or condensation during operation is not pronounced temperature changes permitted that could cause condensation.

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Futher information can be found in the current manual at: www.siemens.com/siprotec

Siemens SIP · Edition No. 8 7/19

Line Differential Protection / 7SD61
Selection and ordering data

1 2 3 4 5 6 7 8 9 10 11

Description 7SD61 numerical line differential protection 87L SIPROTEC 4 for two-line ends, allows transformers in the protection zone
Current transformer Iph = 1 A1), Ie = 1 A1) Iph = 1 A1), Ie = 5 A1)
Auxiliary voltage (Power supply, BI operating voltage) DC 24 to 48 V, trigger level binary input 19 V3) DC 60 to 125 V 2), trigger level binary input 19 V3) DC 110 to 250 V 2), AC 115 to 230 V, trigger level binary input 88 V3) DC 110 to 250 V 2), AC 115 to 230 V, trigger level binary input 176 V3)
Housing, number of binary inputs/outputs Flush-mounting housing with screw-type terminals 19", 7 BI, 5 BO, 1 live-status contact Surface-mounting housing with screw-type terminals 19", 7 BI, 5 BO, 1 live-status contact Flush-mounting housing with plug-in terminals, 19", 7 BI, 5 BO , 1 live-status contact
Region-specific default settings / function versions and language settings Region DE, German language (language changeable) Region world, English language (language changeable) Region US, US-English language (language changeable) Region world, French language (language changeable) Region world, Spanish language (language changeable) Region world, Italian language (language changeable)
System interfaces, functions and hardware Without system interface IEC 60870-5-103 protocol, electric RS232 IEC 60870-5-103 protocol, electric RS485 IEC 60870-5-103 protocol, optical 820 nm, ST connector Further protocols see supplement L
PROFIBUS DP slave, RS485 PROFIBUS DP slave, optical 820 nm, double ring, ST connector4) MODBUS, RS485 MODBUS, optical 820 nm, ST connector4) DNP 3.0, RS485 DNP 3.0, optical 820 nm, ST connector4) IEC 61850, 100 Mbit Ethernet electrical, double, RJ45 connector (EN 100) IEC 61850, 100 Mbit Ethernet, with integrated switch optical, double, LC connector5)

Order No. 7SD610 -

Short code

see next page

2 4 5 6

B F K

A B C D E F

L 0

A B D E G H R S

13 14 15

BI = Binary input BO = Binary output
1) Rated current 1/5 A can be selected by means of jumpers. 2) Transition between the two auxiliary voltage ranges can be selected
by means of jumpers. 3) Setting of the BI thresholds can be made for each binary input via
jumpers in 3 steps.

4) Not possible for surface mounting housing (Order No. pos. 9 = F). For the surface mounted version, please order a device with the appropriate electrical RS485 interface and an external FO-converter
5) Not possible for surface mounting housing (Order No. pos. 9 = F) please order the relay with electrical interface and use a separate fiber-optic switch

7/20 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD61
Selection and ordering data

Description
7SD61 numerical line differential protection 87L SIPROTEC 4 (continued)
DIGSI/Modem interface (on rear of device) and protection interface 1 DIGSI/Modem interface (on rear of device) DIGSI 4, electrical RS232 DIGSI 4, electrical RS485

Protection data interface 1
FO5: Optical 820 nm, 2 ST-plugs, line length up to 1.5 km via multimode FO cable for communication converter or direct FO connection 1)
FO6: Optical 820 nm, 2 ST-plugs, line length up to 3.5 km via multimode FO cable for direct FO connection
FO17: Optical 1300 nm, LC-Duplex-plugs, line length up to 24 km 2) via monomode FO cable for direct FO connection 2)
FO18: Optical 1300 nm, LC-Duplex-plugs, line length up to 60 km via monomode FO cable for direct FO connection 2)3)
FO19: Optical 1550 nm, LC-Duplex-plugs, line length up to 100 km via monomode FO cable for direct FO connection 2)4)
FO30: Optical 820 nm, 2 ST-plugs, line length up to 1.5 km via multimode FO cable for communication networks with IEEE C37.94 interface or direct FO connection 5)

Functions 1 Trip mode 3-pole only without auto reclosure Trip mode 3-pole only with auto reclosure Trip mode 1- and 3-pole without auto reclosure Trip mode 1- and 3-pole with auto reclosure

Back-up functions with emergency or back-up overcurrent protection with emergency or back-up overcurrent and breaker failure protection with directional emergency or back-up overcurrent protection with directional emergency or back-up overcurrent and breaker failure protection

Additional functions 1

4 Remote commands/ 24 Remote indications

Transformer expansions

Voltage-/frequence protection

Restricted earth fault (low impedance)

without external GPS synchronisation of differential protection

with external GPS synchronisation of differential protection

Order No. 7SD610 -

Short code

3
7

R S

B E

1) Communication converter 7XV5662, see Accessories.
2) Device for surface-mounting housing (Order No. pos. 9 = F) will be delivered with external repeater 7XV5461-0Bx00.
3) For distances less than 25 km a set of optical attenuators 7XV5107-0AA00 must be installed to avoid saturation of the receiver element.

14 15

Siemens SIP · Edition No. 8 7/21

Line Differential Protection / 7SD61
Selection and ordering data

AcAccecsessosorireiess
1 2 3 4 5 6 7 8 9 10 11 12 13

Description

Order No.

Opto-electric communication converter CC-XG (connection to communication network)

Converter to interface to X21 or RS422 or G703-64 kbit/s synchronous

communication interfaces

Connection via FO cable for 62.5 / 125 m or 50 / 120 m and

820 nm wavelength (multi-mode FO cable) with ST connector,

max. distance 1.5 km

Electrical connection via X21/RS422 or G703-64 kbit/s interface

7XV5662-0AA00

Opto-electric communication converter CC-2M to G703-E1/-T1 communication networks with 2,048 / 1,554 kbit/s
Converter to interface between optical 820 nm interface and G703-E1/-T1 interface of a communication network Connection via FO cable for 62.5/125 m or 50/120 m and 820 nm wavelength (multi-mode FO cable) with ST connector, max. distance 1.5 km Electrical connection via G703-E1/-T1 interface

7XV5662-0AD00

Opto-electric communication converter (connection to pilot wire)
Converter to interface to a pilot wire or twisted telephone pair (typical 15 km length) Connection via FO cable for 62.5/125 mor 50/120 m and 820 nm wavelength (multi-mode FO cable) with ST connector; max. distance 1.5 km, screw-type terminals to pilot wire

7XV5662-0AC00

Additional interface modules
Protection interface module, optical 820 nm, multi-mode FO cable, ST connector, 1.5 km Protection interface module, optical 820 nm, multi-mode FO cable, ST connector, 3.5 km

C53207-A351-D651-1 C53207-A351-D652-1

Further modules
Protection interface module, optical 1300 nm, mono-mode FO cable, LC-Duplex connector, 24 km
Protection interface module, optical 1300 nm, mono-mode FO cable, LC-Duplex connector, 60 km
Protection interface module, optical 1550 nm, mono-mode FO cable, LC-Duplex connector, 100 km
Protection interface module, optical 820 nm, multi-mode FO cable, ST connector, 1.5 km support of IEEE C37.94

C53207-A351-D655-1 C53207-A351-D656-1 C53207-A351-D657-1 C53207-A351-D658-1

Optical repeaters
Serial repeater (2-channel), optical 1300 nm,mono-mode FO cable, LC-Duplex connector, 24 km
Serial repeater (2-channel), optical 1300 nm,mono-mode FO cable, LC-Duplex connector, 60 km
Serial repeater (2-channel), optical 1550 nm,mono-mode FO cable, LC-Duplex connector, 100 km

7XV5461-0BG00 7XV5461-0BH00 7XV5461-0BJ00

Time synchronizing unit with GPS output GPS 1 sec pulse and time telegram IRIG B/DCF 77

7XV5664-0AA00

Isolation transformer (20 kV) for pilot wire communication
Voltage transformer miniature circuit-breaker Rated current 1.6 A; thermal overload release 1.6 A; overcurrent trip 6 A

7XR9516 3RV1611-1AG14

15
7/22 Siemens SIP · Edition No. 8

Accessories

Line Differential Protection / 7SD61
Selection and ordering data

Description
Connecting cable (copper) Cable between PC/notebook (9-pin connector) and protection unit (9-pin connector) (contained in DIGSI 4, but can be ordered additionally)
Manual for 7SD61 V4.6 English

Order No.
1
7XV5100-4
2
C53000-G1176-C145-4
3

LSP2289-afp.eps

Accessories
Fig. 7/26 Mounting rail for 19" rack

LSP2091-afp.eps

LSP2090-afp.eps

Fig. 7/27 2-pin connector

Fig. 7/28 3-pin connector

LSP2092-afp.eps

LSP2093-afp.eps

Fig. 7/29 Short-circuit link for current contacts

Fig. 7/30 Short-circuit link for voltage contacts/ indications contacts

Description

Order No.

Connector

2-pin 3-pin

C73334-A1-C35-1 C73334-A1-C36-1

Crimp connector
Crimping tool

CI2 0.5 to 1 mm2

0-827039-1 0-827396-1

CI2 0.5 to 2.5 mm2

0-827040-1 0-827397-1

Type III+ 0.75 to 1.5 mm2 0-163083-7 0-163084-2

For type III+ and matching female For CI2 and matching female

0-539635-1 0-539668-2 0-734372-1 1-734387-1

19"-mounting rail

C73165-A63-D200-1

Short-circuit For current terminals

links

For other terminals

C73334-A1-C33-1 C73334-A1-C34-1

Safety cover large for terminals small

C73334-A1-C31-1 C73334-A1-C32-1

Size of Supplier Fig. package

Siemens 7/27

Siemens 7/28

4000

Siemens 7/26

Siemens 7/29

Siemens 7/30

Siemens

1) Your local Siemens representative can inform you on local suppliers.

9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 7/23

Line Differential Protection / 7SD61
Connection diagram

7
Fig. 7/31 Connection diagram
8

Fig. 6/32 Serial interfaces

15
7/24 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD52/53
SIPROTEC 7SD52/53 multi-end differential and distance protection in one relay

Fault locator for one and two terminal measurement for high

accuracy on long lines with high load and high fault resistance. Capacitive charge current compensation increases the sensitivity

of the differential protection on cables and long lines.

Function overview

LSP2173f.eps LSP2314-afp.eps

Fig. 7/33 SIPROTEC 7SD52/53 differential protection relay
Description
The 7SD52/53 relay provides full scheme differential protection and incorporates all functions usually required for the protection of power lines. It is designed for all power and distribution levels and protects lines with two up to six line ends. The relay is designed to provide high-speed and phase-selective fault clearance. The relay uses fiber-optic cables or digital communication networks to exchange telegrams and includes special features for the use in multiplexed communication networks. Also pilot wires connections can be used with an external converter. This contributes toward improved reliability and availability of the electrical power system.
The relay is suitable for single and three-phase tripping applications for two up to six line ends. Also, transformers and compensation coils within the differential protection zone are protected as are serial and parallel-compensated lines and cables. The relays may be employed with any type of system grounding.
The relay also provides a full-scheme and non-switched distance protection as an optional main 2 protection. Several teleprotection schemes ensure maximum selectivity and high-speed tripping time.
The units measure the delay time in the communication networks and adaptively match their measurements accordingly.
A special GPS-option allows the use of the relays in communication networks, where the delay time in the transmit and receive path may be quite different.
The 7SD52/53 has the following features:
2 full-scheme main protections in one unit (differential and distance protection)
High-speed tripping 10 15 ms The serial protection interfaces (R2R interfaces) of the relays can
flexibly be adapted to the requirements of all communication media available. If the communication method is changed, flexible retrofitting of communication modules to the existing configuration is possible. Tolerates loss of one data connection in a ring topology (routing in 120 ms). The differential protection scheme is fully available in a chain topology. Browser-based commissioning tool.

Protection functions ·Differential protection with phase-segregated measurement
(87L, 87T) ·Restricted ground-fault protection (87N) if a transformer is
within the protection zone ·Sensitive meas. stage f. high-resist. faults ·Non-switched distance protection with 7 measuring systems
(21/21N) ·High resistance ground (earth)-fault protection for single and
three-pole tripping (50N/51N/67N) ·Phase-selective intertripping (85) ·Ground-fault detection in isolated and resonant-grounded
networks ·Tele (pilot) protection (85/21, 85/67N) ·Weak-infeed protection (27WI) ·Fault locator (FL) ·Power swing detection/tripping (68/68T) ·3-stage overcurrent protection (50, 50N, 51, 51N) ·STUB bus protection (50 STUB) ·Switch-onto-fault protection (50HS) ·Over/undervoltage protection (59/27) ·Over/underfrequency protection (81O/U) ·Auto-reclosure (79), Synchro-check (25) ·Breaker failure protection (50BF) ·Overload protection (49) ·Lockout function (86)
Control functions ·Commands for control of CB and isolators
Monitoring functions ·Self-supervision of relay and protection data (R2R)
communication ·Trip circuit supervision (74TC) ·Measured-value supervision ·Oscillographic fault recording ·Event logging/fault logging ·Switching statistics
Front design ·User-friendly local operation ·PC front port for relay setting ·Function keys and 14 LEDs f. local alarm
Communication interfaces ·2 serial protection data (R2R) interfaces for ring and chain
topology ·Front interface for connecting a PC ·System interface for connection to a control system via various
protocols IEC 61850 Ethernet IEC 60870-5-103 PROFIBUS DP and DNP 3 ·Rear-side service/modem interface ·Time synchronization via IRIG-B or DCF77 or system interface

2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 7/25

Line Differential Protection / 7SD52/53
Application

Application

1 ANSI

Protection functions

87L

I for lines / cables

ANSI 85/67N

Protection functions Teleprotection for earth(ground)-fault protection

87T

87N

21/21N

68/68T

I for lines / cables with transformers Low impedance restricted ground-fault protection for transformers Phase-selective intertrip, remote trip
Lockout function
Distance protection Fault locator
Power swing detection/tripping

50/50N/51/51N Overcurrent protection

50HS

Instantaneous high-current tripping (switch-onto-fault)

59/27

Overvoltage/undervoltage protection

81O/U

Over/underfrequency protection

Synchro-check

Single or three-pole auto-reclosure with new adaptive

technology

Overload protection

85/21

27WI

Teleprotection for distance protection Weak-infeed protection

50BF 74TC

Breaker-failure protection Trip circuit supervision

50N/51N/67N Directional earth(ground)-fault protection

50 STUB

STUB-bus overcurrent stage

12 13
Fig. 7/34
14

*) Option

15
7/26 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD52/53
Application

Fig. 7/35 Application for three line ends (Ring topology)

Typical applications
SIPROTEC 7SD52/53 is a full-scheme differential protection relay for two up to six line ends, incorporating all the additional functions for protection of overhead lines and cables at all voltage levels. Also transformers and compensation coils within the protection zone are protected. The 7SD52/53 is suitable for single-pole and three-pole tripping. The power system star point can be solid or impedance-grounded (earthed), resonant-grounded via Peterson coil or isolated. On the TAP-line, the 7SD52/53 differential relay is connected to current (CT) and optionally voltage (VT) transformers. For the differential functions, only CTs are necessary. By connecting the relay to VTs, the integrated "main 2" distance protection can be applied (full-scheme, nonswitched). Therefore, no separate distance protection relay is required.
The link to the other relays is made by multi-mode or mono-mode FO cables. There are 5 options available, which correspondingly cover:
·820 nm, up to 1.5 km, multi-mode
·820 nm, up to 3.5 km, multi-mode
·1300 nm, up to 24 km, mono-mode
·820 nm support of the IEEE C37.94 interface
·1300 nm, up to 60 km, mono-mode
·1550 nm, up to 100 km, mono-mode
Direct fiber-optic connection offers high-speed data exchange with 512 kbit/s and improves the speed for remote signaling.
At the main line two differential relays are connected to CTs. The communication is made via a multiplexed communication network.
The 7SD52/53 offers many features to reliably and safely handle data exchange via communication networks.

Depending on the bandwidth available in the communication system, 64, 128 or 512 kbits/s can be selected for the X21 (RS422) interface; the G703 interface with 64 kbit/s, and G703-E1 (2,048 kbit/s) or G703-T1 (1,554 kbit/s). Furthermore the 7SD610 supports the IEEE C37.94 interface with 1/ 2 / 4 and 8 timeslots.
The connection to the communication device is effected via cost-effective 820 nm interface with multi-mode FO cables. A communication converter converts the optical to electrical signals. This offers an interference-free and isolated connection between the relay and the communication device.
Cost-effective power system management
The SIPROTEC 4 units are numerical relays which also provide control and monitoring functions and therefore support the user in view of a cost-effective power system management. The security and reliability of power supply is increased as a result of minimizing the use of hardware.
The local operation has been designed according to ergonomic criteria. Large, easy-to-read backlit displays are provided.
The SIPROTEC 4 units have a uniform design and a degree of functionality which represents a benchmark-level of performance in protection and control. If the requirements for protection, control or interlocking change, it is possible in the majority of cases to implement such changes by means of parameterization using DIGSI 4 without having to change the hardware.
The use of powerful microcontrollers and the application of digital measured-value conditioning and processing largely suppresses the influence of higher-frequency transients, harmonics and DC components.

7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 7/27

Line Differential Protection / 7SD52/53
Construction

Construction

Connection techniques and housing

with many advantages

, ½, ²/, and -rack sizes:

These are the available housing widths of the 7SD52/53 relays, referred to a

19" module frame system. This means

that previous models can always be

replaced. The height is a uniform 245 mm for flush-mounting housings and 266 mm

for surface-mounting housings for all

housing widths. All cables can be con-

nected with or without ring lugs. Plug-in terminals are available as an option. It

is thus possible to employ prefabricated

cable harnesses. In the case of surface

mounting on a panel, the connection

Fig. 7/36 Flush-mounting housing with

terminals are located above and below in the form of screw-type terminals. The

screw-type terminals

communication interfaces are located in a

sloped case at the top and bottom of the

housing.

LSP2174-afp.tif LSP2166-afp.tif

Fig. 7/37 Rear view with screw-type terminals and serial interfaces

LSP2219-afp.eps LSP2237-afp.tif

9 10

Fig. 7/38 Surface-mounting housing with screw-type terminals

Fig. 7/39 Communication interfaces in a sloped case in a surfacemounting housing

15
7/28 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD52/53
Protection functions

Protection functions
Differential protection (ANSI 87L, 87T, 87N)
The differential protection function has the following features:
·It is possible to select the operating mode as "main" or as "main 1", if the back-up distance protection is activated as "main 2".
·Measurements are performed separately for each phase; thus the trip sensitivity is independent of the fault type.
·An adaptive, sensitive measurement method with high sensitivity for differential fault currents below the rated current offers the detection of highly resistive faults. This trip element uses special filters, which offers high security even with high level DC-components in the short-circuit current. The trip time of this stage is about 30 ms.
·A high-set differential trip stage which clears differential fault currents higher than the rated current within 10 15 ms offers fast tripping time and high-speed fault clearence time.
·When a long line or cable is switched on, transient charge currents load the line. To avoid a higher setting of the sensitive differential trip stage, this setpoint may be increased for a settable time. This offers greater sensitivity under normal load conditions.
·With the setting of the CT-errors the relay automatically calculates the restraint/stabilization current and adapts its permissible sensitivity according to the CT's data in the differential configuration, optimizing sensitivity.
·Different CT ratios at the line ends are handled inside the relay. The mismatch of 1 to 6 is allowed.
·The differential protection trip can be guarded with an overcurrent pickup. Thus differential current and overcurrent lead to a final trip decision.
·Easy to set tripping characteristic. Because the relay works adaptively, only the setpoint IDiff> (sensitive stage) and IDiff>> (high-set current differential stage) must be set according to the charge current of the line/cable.
·With an optional capacitive charge current compensation, the sensitivity can be increased to 40 % of the normal setting of IDiff>. This function is recommended for long cables and long lines.
·Differential and restraint currents are monitored continuously during normal operation and are displayed as operational measurements.
·High stability during external faults even with different current transformers saturation level. For an external fault, only 5 ms saturation-free time are necessary to guarantee the stability of the differential configuration.
·With transformers or compensation coils in the protection zone, the sensitive trip stage can be blocked by an inrush detection function. It works with the second harmonic of the measured current which is compared with the fundamental component.
·With transformers in the protection zone, vector group adaptation and matching of different CT ratios are carried out in the relay. Additionally, the zero-sequence current flowing through an grounded neutral is eliminated from the differential measurement. The 7SD52/53 therefore works like a transformer differential relay, whereas the line ends may be far away.

Fig. 7/40 Tripping characteristic
·A more sensitive protection for transformers within the protection zone is given by measurement of the star-point current on an grounded winding. Therefore the IE current measuring input has to be used. If the sum of the phase currents of winding is compared with the measured star-point current, a sensitive ground-current differential protection (REF) can be implemented. This function is substantially more sensitive than the differential protection during faults to ground in a winding, detecting fault currents as small as 10 % of the transformer rated current.
Enhanced communication features for communication networks
The data required for the differential calculations are cyclically exchanged in full-duplex mode in form of synchronous, serial telegrams between the protection units. The telegrams are secured with CRC check sums, so that transmission errors in a communication network are immediately detected.
·Data communication is immune to electromagnetic interference because fiber-optic cables are employed in the critical region
·Supervision of each individual incoming telegram and of the entire communication path between the units without additional equipment.
·Unambiguous identification of each unit is ensured by assignment of a settable communication address within a differential protection topology. Only those units mutually known to each other can cooperate. Incorrect interconnection of the communication links results in blocking of the protection system.
·Detection of reflected telegrams in the communication system.
·Detection of delay time changes in communication networks.
·Measurement of the delay time to the remote line ends with dynamic compensation of the delay in the differential measurement. Supervision of the maximum permissible delay time is included.
·Generation of alarms on heavily disturbed communication links. Faulty telegram counters are available as operational measurement. (continued on next page)

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 7/29

Line Differential Protection / 7SD52/53
Protection functions

1 2 3 4 5 6 7 8 9 10 11

·With a GPS high-precision 1-s pulse from a GPS receiver the relays can be synchronized with an absolute, exact time at each line end. In this way, the delay in the receive and transmit path can be measured exactly. With this optional feature the relay can be used in communication networks where this delay times are quite different.

Phase-selective intertrip and remote trip/ indications

Normally the differential fault current is calculated for each line end nearly at the same time. This leads to fast and uniform tripping times. Under weak infeed conditions, especially when the differential function is combined with an overcurrent pickup a phase-selective intertrip offers a tripping of all line ends.

·7SD52/53 has 4 intertrip signals which Fig. 7/41 Differential protection in ring or chain topology

are transmitted in high-speed (< 20 ms)

to the other line ends. These intertrip

signals can also be initiated by an external relay via binary

·The two-end line is a special case, because when the main

inputs and therefore be used to indicate, for example, a

connection is interrupted, the communication switches over

directional decision of the backup distance relay.

from a main path to a secondary path. This hot standby trans-

·In addition, 4 high-speed remote trip signals are available, which may be initiated by an external or internal event.
·24 remote signals can be freely assigned to inputs and outputs at each line end and are circulating between the different devices.
Communication topologies / modes of operation

mission function ensures a high availability of the system and protects differential protection against communication route failure on important lines.
·In a ring topology, one line end can be logged out from the differential protection topology for service or maintenance reasons by a signal via binary input. Checks for the breaker position and load current are made before this logout is initi-

The differential relays may work in a ring or daisy chain line topology. Use of a test mode offer advantages under commis-

ated. In a chain topology, the relays at the end of the line can be logged out from the differential protection topology.

sioning and service conditions.

·The whole configuration can be set up into a test mode. All

·The system tolerates the loss of one data connection in a ring topology. The ring topology is rerouted within 20 ms forming then a chain topology, while the differential protection func-

functions and indications are available except the breakers are not tripped. The local relay can be tested and no trip or intertrip reaction is effected by the other relays.

tion is immediately reactivated.

·When the communication connections need to be reduced or when these are not available, the whole system is able to function without interruption as chain topology. At the line ends, only cost-effective 7SD52/53 relays with one protection interface are necessary for this application.

15
7/30 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD52/53
Protection functions

Distance protection (ANSI 21, 21N)
7SD52/53 provides a non-switched distance protection featuring all well-proven algogrithms of 7SA522 and 7SA6. It is possible to select the operating mode "main" or "main 2", if the back-up differential is activated as "main 1". By parallel calculation and monitoring of all six impedance loops, a high degree of sensitivity and selectivity is achieved for all types of faults. The shortest tripping time is less than one cycle. All methods of neutral-point connection (resonant grounding, isolated, solid or low-resistance grounding) are reliably dealt with. Single and three-pole tripping is possible. Overhead lines can be equipped with or without series capacitor compensation.
Quadrilateral and mho characteristics
The 7SD52/53 relay provides quadrilateral as well as mho zone characteristics. Both characteristics can be used separately for phase and ground (earth) faults. Resistance ground (earth) faults can, for instance, be covered with the quadrilateral characteristic and phase faults with the mho characteristic.
Alternatively, the quadrilateral characteristic is available with 4 different pickup methods:
·Overcurrent pickup I>>
·Voltage-dependent overcurrent pickup V/I
·Voltage-dependent and phase angle-dependent overcurrent pickup V/I/
·Impedance pickup Z<
Load zone
In order to guarantee a reliable discrimination between load operation and short-circuit especially on long high loaded lines the relay is equipped with a selectable load encroachment characteristic. Impedances within this load encroachment characteristic prevent the distance zones from unwanted tripping.
Absolute phase-selectivity
The distance protection incorporates a well-proven highly sophisticated phase selection algorithm. The pickup of unfaulted loops is reliably eliminated to prevent the adverse influence of currents and voltages in the fault-free loops. This phase selection algorithm achieves single-pole tripping and correct distance measurement in a wide application range.
Parallel line compensation
The influence of wrong distance measurement due to parallel lines can be compensated by feeding the neutral current of the parallel line to the relay. Parallel line compensation can be used for distance protection as well as for fault locating.
7 distance zones
6 independent distance zones and one separate overreach zone are available. Each distance zone has dedicated time stages, partly separate for single-phase or multi-phase faults. Ground (earth) faults are detected by monitoring the neutral current 3I0 and the zero-sequence voltage 3V0.
The quadrilateral tripping characteristic permits separate setting of the reactance X and the resistance R. The resistance section R can be set separately for faults with and without ground involvement. This characteristic has therefore an optimal performance

Fig. 7/42 Distance protection: quadrilateral characteristic
Fig. 7/43 Distance protection: mho characteristic in case of faults with fault resistance. The distance zones can be set forward, reverse or non-directional. Sound phase polarization and voltage memory provides a dynamically unlimited directional sensitivity. Mho The mho tripping characteristic provides sound phase respectively memory polarization for all distance zones. The diagram shows characteristic without the expansion due to polarizing. During a forward fault the polarizing expands the mho circle towards the source so that the origin is included. This mho circle expansion guarantees safe and selective operation for all types of faults, even for close-in faults.

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Line Differential Protection / 7SD52/53
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Elimination of interference signals
Digital filters render the unit immune to interference signals contained in the measured values. In particular, the influence of DC components, capacitive voltage transformers and frequency changes is considerably reduced. A special measuring method is employed in order to assure protection selectivity during saturation of the current transformers.
Measuring voltage monitoring
Tripping of the distance protection is blocked automatically in the event of failure of the measuring voltage, thus preventing spurious tripping.
The measuring voltage is monitored by the integrated fuse failure monitor. Distance protection is blocked if either the fuse failure monitor or the auxiliary contact of the voltage transformer protection switch operates and, in this case, the EMERGENCY definite-time overcurrent protection can be activated.

Fig. 7/44 Power swing current and voltage wave forms

LSP2311-afp.tif

Power swing detection (ANSI 68, 68T)
Dynamic transient reactions, for instance short-circuits, load fluctuations, autoreclosures or switching operations can cause power swings in the transmission network. During power swings, large currents along with small voltages can cause unwanted tripping of distance protection relays. To avoid uncontrolled tripping of the distance protection and to achieve controlled tripping in the event of loss of synchronism, the 7SD52/53 relay is equipped with an efficient power swing detection function. Power swings can be detected under symmetrical load conditions as well as during single-pole auto-reclosures.

Fig. 7/45 Power swing circle diagram

LSP2312-afp.tif

Tele (pilot) protection for distance protection (ANSI 85-21)
A teleprotection function is available for fast clearance of faults up to 100 % of the line length. The following operating modes may be selected: ·PUTT, permissive underreaching zone transfer trip ·POTT, permissive overreaching zone transfer trip ·UNBLOCKING ·BLOCKING ·Directional comparison pickup ·Pilot-wire comparison ·Reverse interlocking ·DUTT, direct underreaching zone transfer trip (together with
Direct Transfer Trip function)
The carrier send and receive signals are available as binary inputs and outputs and can be freely assigned to each physical relay input or output. At least one channel is required for each direction.

Common transmission channels are power-line carrier, microwave radio and fiber-optic links. The serial protection interface can be used for direct connection to a digital communication network, fiber-optic or pilot-wire link as well.
7SD52/53 also permits the transfer of phase-selective signals. This feature is particularly advantageous as it ensures reliable single-pole tripping, if two single-pole faults occur on different lines. The transmission methods are suitable also for lines with three ends (three-terminal lines).
Phase-selective transmission is also possible with multi-end applications, if some user-specific linkages are implemented by way of the integrated CFC logic. During disturbances in the transmission receiver or on the transmission circuit, the teleprotection function can be blocked by a binary input signal without losing the zone selectivity. The control of the overreach zone Z1B (zone extension) can be switched over to the auto-reclosure function. A transient blocking function (Current reversal guard) is provided in order to suppress interference signals during tripping of parallel lines.

7/32 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD52/53
Protection functions

Direct transfer tripping

Under certain conditions on the power system it is necessary to execute remote tripping of the circuit-breaker. The 7SD52/53

relay is equipped with phase-selective "external trip inputs" that

can be assigned to the received inter-trip signal for this purpose.

Weak-infeed protection: echo and/or trip (ANSI 27 WI)

To prevent delayed tripping of permissive schemes during weak

or zero infeed situations, an echo function is provided. If no

fault detector is picked up at the weak-infeed end of the line, the signal received here is returned as echo to allow accelerated

tripping at the strong infeed end of the line. It is also possible

to initiate tripping at the weak-infeed end. A phase-selective

1-pole or 3-pole trip is issued if a permissive trip signal (POTT or

Unblocking) is received and if the phase-ground voltage drops

correspondingly. As an option, the weak-infeed logic can be

equipped according to a French specification.

Directional ground(earth)-fault protection for highresistance faults (ANSI 50N, 51N, 67N)
In grounded (earthed) networks, it may happen that the distance protection sensitivity is not sufficient to detect highresistance ground (earth) faults. The 7SD52/53 protection relay has therefore protection functions for faults of this nature.
The ground (earth)-fault overcurrent protection can be used with 3 definite-time stages and one inverse-time stage (IDMT). A 4th definite-time stage can be applied instead of the 1st inverse-time stage.
Inverse-time characteristics according to IEC 60255-3 and ANSI/ IEEE are provided (see "Technical data"). An additional logarithmic inverse-time characteristic is also available.
The direction decision can be determined by the neutral current and the zero-sequence voltage or by the negative-sequence components V2 and I2. In addition or as an alternative to the directional determination with zero-sequence voltage, the starpoint current of a grounded (earthed) power transformer may also be used for polarization. Dual polarization applications can therefore be fulfilled.
Alternatively, the direction can be determined by evaluation of zero-sequence power. Each overcurrent stage can be set in forward or reverse direction or for both directions (non-directional). As an option the 7SD52/53 relay can be provided with a sensitive neutral (residual) current transformer. This feature provides a measuring range for the neutral (residual) current from 5 mA to 100 A with a nominal relay current of 1 A and from 5 mA to 500 A with a nominal relay current of 5 A. Thus the ground (earth)-fault overcurrent protection can be applied with extreme sensitivity.
The function is equipped with special digital filter algorithms, providing the elimination of higher harmonics. This feature is particularly important for low zero-sequence fault currents which usually have a high content of 3rd and 5th harmonics. Inrush stabilization and instantaneous switch-onto-fault trip can be activated separately for each stage as well.
Different operating modes can be selected. The ground(earth)fault protection is suitable for three-phase and, optionally, for single-phase tripping by means of a sophisticated phase selector. It may be blocked during the dead time of single-pole autoreclose cycles or during pickup of the distance protection.

0,14

( ) t =

0,02

I / Ip -1

Fig. 7/46 Normal inverse
Tele (pilot) protection for directional ground(earth)-fault protection (ANSI 85-67N)
The directional ground(earth)-fault overcurrent protection can be combined with one of the following teleprotection schemes: ·Directional comparison ·BLOCKING ·UNBLOCKING
The transient blocking function (current reversal guard) is also provided in order to suppress interference signals during tripping of parallel lines.
The pilot functions for distance protection and for ground(earth)-fault protection can use the same signaling channel or two separate and redundant channels.
Overcurrent protection (ANSI 50, 50N, 51, 51N)
The 7SD52/53 provides a backup over-current protection. Two definite-time stages and one inverse-time stage (IDMTL) are available, separately for phase currents and for the neutral (residual) current. Two operating modes are selectable. The function can run in parallel to the differential protection and the distance protection or only during interruption of the protection communication and/or failure of the voltage in the VT secondary circuit (emergency operation). The secondary voltage failure can be detected by the integrated fuse failure monitor or via a binary input from a VT miniature circuit-breaker (VT m.c.b. trip).
The following inverse-time characteristics according to IEC 60255-3 and ANSI/IEEE are provided: ·Inverse ·Short inverse ·Long inverse ·Moderately inverse ·Very inverse ·Extremely inverse ·Definite inverse

5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 7/33

Line Differential Protection / 7SD52/53
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

STUB bus overcurrent protection (ANSI 50(N)-STUB)
The STUB bus overcurrent protection is a separate definite-time overcurrent stage. It can be activated from a binary input signaling the line isolator (disconnector) is open. Settings are available for phase and ground (earth)-faults.
Instantaneous high-speed switch-onto-fault overcurrent protection (ANSI 50HS)
Instantaneous tripping is possible when energizing a faulty line. In the event of large fault currents, the high-speed switch-ontofault overcurrent stage can initiate very fast 3-pole tripping.
With lower fault currents, instantaneous tripping after switchonto-fault is also possible if the breaker positions at the line ends are monitored and
connected to the relays. This breaker position monitor offers a high-speed trip during switch-onto-fault conditions. with the overreach distance zone Z1B or just with pickup in any zone.
The switch-onto-fault initiation can be detected via the binary input "manual close" or automatically via measurement.
Fault locator
The integrated fault locator calculates the fault impedance and the distance-to-fault. The result is displayed in ohms, miles, kilometers or in percent of the line length. Parallel line and load current compensation is also available.
As an option for a line with two ends, a fault locator function with measurement at both ends of the line is available.Thanks to this feature, accuracy of measurement on long lines under high load conditions and high fault resistances is considerably increased.
Overvoltage protection, undervoltage protection (ANSI 59, 27)
A voltage rise can occur on long lines that are operating at noload or are only lightly loaded. The 7SD52/53 contains a number of overvoltage measuring elements. Each measuring element is of two-stage design. The following measuring elements are available: ·Phase-to-ground overvoltage ·Phase-to-phase overvoltage ·Zero-sequence overvoltage
The zero-sequence voltage can be connected to the 4th voltage input or be derived from the phase voltages. ·Positive-sequence overvoltage of the local end or calculated for the remote end of the line (compounding). ·Negative-sequence overvoltage
Tripping by the overvoltage measuring elements can be effected either at the local circuit-breaker or at the remote station by means of a transmitted signal.
The 7SD52/53 is fitted, in addition, with three two-stage undervoltage measuring elements: ·Phase-to-ground undervoltage ·Phase-to-phase undervoltage ·Positive-sequence undervoltage
The undervoltage measuring elements can be blocked by means of a minimum current criterion and by means of binary inputs.

Frequency protection (ANSI 81O/U)
Frequency protection can be used for overfrequency and underfrequency protection. Unwanted frequency changes in the network can be detected and the load can be removed at a specified frequency setting. Frequency protection can be used over a wide frequency range (45 to 55, 55 to 65 Hz). There are four elements (selectable as overfrequency or underfrequency) and each element can be delayed separately.
Breaker failure protection (ANSI 50BF)
The 7SD52/53 relay incorporates a two-stage breaker failure protection to detect the failure of tripping command execution, for example due to a defective ciruit-breaker. The current detection logic is phase-segregated and can therefore also be used in single-pole tripping schemes. If the fault current is not interrupted after a settable time delay has expired, a retrip command or a busbar trip command is generated. The breaker failure protection can be initiated by all integrated protection functions as well as by external devices via binary input signals.
Auto-reclosure (ANSI 79)
The 7SD52/53 relay is equipped with an auto-reclose function (AR). The function includes several operating modes:
·3-pole auto-reclosure for all types of faults; different dead times are available depending the type of fault
·1-pole auto-reclosure for 1-phase faults, no reclosing for multiphase faults
·1-pole auto-reclosure for 1-phase faults and for 2-phase faults without ground, no reclosing for multi-phase faults
·1-pole auto-reclosure for 1-phase and 3-pole auto-reclosing for multi-phase faults
·1-pole auto-reclosure for 1-phase faults and 2-phase faults without ground and 3-pole auto-reclosure for other faults
·Multiple-shot auto-reclosure
·Interaction with an external device for auto-reclosure via binary inputs and outputs
·Control of the integrated AR function by external protection
·Adaptive auto-reclosure. Only one line end is closed after the dead time. If the fault persists this line end is switched off. Otherwise the other line ends are closed via a command over the communication links. This avoids stress when heavy fault currents are fed from all line ends again.
·Interaction with the internal or an external synchro-check
·Monitoring of the circuit-breaker auxiliary contacts
In addition to the above-mentioned operating modes, several other operating principles can be employed by means of the integrated programmable logic (CFC).
Integration of auto-reclosure in the feeder protection allows evaluation of the line-side voltages. A number of voltagedependent supplementary functions are thus available:
·DLC By means of dead-line check, reclosure is effected only when the line is deenergized (prevention of asynchronous breaker closure).

7/34 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD52/53
Protection functions

·ADT The adaptive dead time is employed only if auto-reclosure at the remote station was successful (reduction of stress on equipment).
·RDT Reduced dead time is employed in conjunction with autoreclosure where no tele-protection method is employed: When faults within the zone extension, but external to the protected line, are switched off for rapid auto-reclosure (RAR), the RDT function decides on the basis of measurement of the return voltage from the remote station which has not tripped whether or not to reduce the dead time.
Synchronism check (ANSI 25)
Where two network sections are switched in by control command or following a 3-pole auto-reclosure, it must be ensured that both network sections are mutually synchronous. For this purpose, a synchronism-check function is provided. After verification of the network synchronism the function releases the CLOSE command. Alternatively, reclosing can be enabled for different criteria, e.g., checking that the busbar or line is not carrying a voltage (dead line or dead bus).
Thermal overload protection (ANSI 49)
A built-in overload protection with a current and thermal alarm stage is provided for the thermal protection of cables and transformers. The trip time characteristics are exponential functions according to IEC 60255-8. The preload is thus considered in the trip times for overloads. An adjustable alarm stage can initiate an alarm before tripping is initiated.
Monitoring and supervision functions
The 7SD52/53 relay provides comprehensive monitoring functions covering both hardware and software. Furthermore, the measured values are continuously checked for plausibility. Therefore the current and voltage transformers are also included in this monitoring system.
Current transformer / Monitoring functions
A broken wire between the CTs and relay inputs under load may lead to malopera- tion of a differential relay if the load current exceeds the differential setpoint. The 7SD52/53 provides fast broken wire supervision which immediatelly blocks all line ends if a broken wire condition is measured by a local relay. This avoids mal-operation due to broken wire condition. Only the phase where the broken wire is detected is blocked. The other phases remain under differential operation.
Fuse failure monitoring
If any measured voltage is not present due to short-circuit or open circuit in the voltage transformer secondary circuit the distance protection would respond with an unwanted trip due to this loss of voltage. This secondary voltage interruption can be detected by means of the integrated fuse failure monitor. Immediate blocking of distance protection is provided for all types of secondary voltage failures.
Additional measurement supervision functions are
·Symmetry of voltages and currents
·Summation of currents and voltages

Trip circuit supervision (ANSI 74TC)
One or two binary inputs for each circuit- breaker pole can be used for monitoring the circuit-breaker trip coils including the connecting cables. An alarm signal is issued whenever the circuit is interrupted.
Lockout (ANSI 86)
All binary outputs can be stored like LEDs and reset using the LED reset key. The lockout state is also stored in the event of supply voltage failure. Reclosure can only be issued after the lockout state is reset.
Local measured values
The measured values are calculated from the measured current and voltage signals along with the power factor (cos ), the frequency, the active and reactive power. Measured values are displayed as primary or secondary values or in percent of the specific line rated current and voltage. The relay uses a 20 bit high-resolution AD converter and the analog inputs are factorycalibrated, so a high accuracy is reached.
The following values are available for measured-value processing:
·Currents 3 x IPhase, 3I0, IE, IE sensitive ·Voltages 3 x VPhase-Ground, 3 x VPhase-Phase, 3V0, Ven, VSYNC,
VCOMP ·Symmetrical components I1, I2, V1, V2 ·Real power P (Watt), reactive power Q (Var),
apparent power S (VA)
·Power factor PF (= cos )
·Frequency f
·Differential and restraint current per phase
·Load impedances with directional indication 3 x RPhase-Ground, XPhase-Ground 3 x RPhase-Phase, XPhase-Phase
·Long term mean values 3 x IPhase; I1; P; P+; P-; Q; Q+; Q-; S
·Minimum/maximum memory 3 x IPhase; I1; 3 x VPhase-Ground 3 x VPhase-Phase, 3V0; V1; P+; P-; Q+; Q-; S; f; power factor (+); power factor (-); from mean values 3 x IPhase; I1; P; Q; S
·Energy meters Wp+; Wp-; WQ+; WQ·Availability of the data connection to the remote line ends per
minute and per hour Regarding delay time measuring with the GPS-version the absolute time for transmit and receive path is displayed separately.
Limit value monitoring: Limit values are monitored by means of the CFC. Commands can be derived from these limit value indications.

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Siemens SIP · Edition No. 8 7/35

Line Differential Protection / 7SD52/53
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

LSP2845.tif

Fig. 7/47 Browser-aided commissioning: Phasor diagram

WEB Monitor Internet technology simplifies visualization

Fig. 7/48 Browser-aided commissioning: Differential protection tripping characteristic

LSP2846.tif

Stability can be checked by using the operating characteristic as well as the calculated differential and restraint values in the browser windows.

If the distance protection is active, then the valid zone characteristic (quadrilateral/mho) is displayed.
Event log and trip log messages are also available. Remote control can be used, if the local front panel cannot be accessed.

7/36 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD52/53
Protection functions

Control and automation functions
Control
In addition to the protection functions, the SIPROTEC 4 units also support all control and monitoring functions that are required for operating medium-voltage or high-voltage substations.
The main application is reliable control of switching and other processes.
The status of primary equipment or auxiliary devices can be obtained from auxiliary contacts and communicated via binary inputs. Therefore it is possible to detect and indicate both the OPEN and CLOSED position or a fault or intermediate circuitbreaker or auxiliary contact position.
The switchgear or circuit-breaker can be controlled via: integrated operator panel binary inputs substation control and protection system DIGSI 4
Command processing
All the functionality of command processing is offered. This includes the processing of single and double commands with or without feedback, sophisticated monitoring of the control hardware and software, checking of the external process, control actions using functions such as runtime monitoring and automatic command termination after output. Here are some typical applications: ·Single and double commands using 1, 1 plus 1 common or
2 trip contacts ·User-definable bay interlocks ·Operating sequences combining several switching operations
such as control of circuit-breakers, disconnectors and grounding switches ·Triggering of switching operations, indications or alarm by combination with existing information
Automation/user-defined logic
With integrated logic, the user can set, via a graphic interface (CFC), specific functions for the automation of switchgear or substation. Functions are activated via function keys, binary input or via communication interface.
Switching authority
Switching authority is determined according to parameters, communication or by key-operated switch (when available).
If a source is set to "LOCAL", only local switching operations are possible. The following sequence of switching authority is laid down: "LOCAL"; DIGSI PC program, "REMOTE"
Every switching operation and change of breaker position is kept in the status indication memory. The switch command source, switching device, cause (i.e. spontaneous change or command) and result of a switching operation are retained.

1 2 3 4 5 6 7 8 9 10 11 12 13 14

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Line Differential Protection / 7SD52/53
Communication

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Communication

With respect to communication, particular emphasis has been placed on high levels of flexibility, data integrity and utilization of standards common in energy automation. The design of the communication modules permits interchangeability on the one hand, and on the other hand provides openness for future standards (for example, Industrial Ethernet).

Rear-mounted interfaces
Two communication modules located on the rear of the unit incorporate optional equipment complements and readily permit retrofitting. They assure the ability to comply with the requirements of different communication interfaces.
The interfaces make provision for the following applications:
·Service /modem interface By means of the RS232/RS485 or optical interface, it is possible to efficiently operate a number of protection units centrally via DIGSI 4 or standard browser. Remote operation is possible on connection of a modem. This offers the advantage of rapid fault clarification, especially in the case of unmanned power plants. With the optical version, centralized operation can be implemented by means of a star coupler.
·System interface This interface is used to carry out communication with a control or protection and control system and supports a variety of communication protocols and interface designs, depending on the module connected.

Fig. 7/49 IEC 60870-5-103 star-type RS232 copper conductor connection or fiber-optic connection

Commissioning aid via a standard Web browser
In the case of the 7SD52/53, a PC with a standard browser can be connected to the local PC interface or to the service interface (refer to "Commissioning program"). The relays include a small Web server that sends its HTML pages to the browser via an established dial-up network connection.
Retrofitting: Modules for every type of communication
Communication modules for retrofitting are available for the entire SIPROTEC 4 unit range. These ensure that, where different communication interfaces (electrical or optical) and protocols (IEC 61850 Ethernet, IEC 60870-5-103, PROFIBUS DP, DNP 3, DIGSI, etc.) are required, such demands can be met.

Fig. 7/50 Bus structure for station bus with Ethernet and IEC 61850
Safe bus architecture ·RS485 bus
With this data transmission via copper conductors electromagnetic fault influences are largely eliminated by the use of twisted-pair conductors. Upon failure of a unit, the remaining system continues to operate without any disturbances. ·Fiber-optic double ring circuit The fiber-optic double ring circuit is immune to electromagnetic interference. Upon failure of a section between two units, the communication system continues to operate without disturbance.
It is generally impossible to communicate with a unit that has failed. If a unit were to fail, there is no effect on the communication with the rest of the system.

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7/38 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD52/53
Communication

IEC 61850 Ethernet

LSP2163-afpen.tif

The Ethernet-based IEC 61850 protocol is the worldwide standard for protection

LSP2164-afp.tif

and control systems used by power supply

corporations. Siemens was the first

manufacturer to support this standard. By means of this protocol, information can

also be exchanged directly between bay

units so as to set up simple masterless

systems for bay and system interlocking.

Access to the units via the Ethernet bus is

also possible with DIGSI.

IEC 60870-5-103
IEC 60870-5-103 is an internationally standardized protocol for the efficient communication in the protected area. IEC 60870-5-103 is supported by a number of protection device manufacturers and is used worldwide.

Fig. 7/51 RS232/RS485 electrical communication module

Fig. 7/52 PROFIBUS communication module,

optical double-ring

LSP2162-afpen.tif

PROFIBUS DP

LSP3.01-0021.tif

PROFIBUS DP is an industry-recognized standard for communications and is sup-

ported by a number of PLC and protection

device manufacturers.

DNP 3.0

DNP 3.0 (Distributed Network Protocol

Version 3) is a messaging-based commu- Fig. 7/53 820 nm fiber-optic communication Fig. 7/54 Fiber-optic Ethernet communication

nication protocol. The SIPROTEC 4 units are fully Level 1 and Level 2 compliant

module

module for IEC 61850 with integrated Ethernet switch

with DNP 3.0. DNP 3.0 is supported by a

number of protection device manufactur-

ers.

Fig. 7/55 System solution: Communications

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Line Differential Protection / 7SD52/53
Communication

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

System solutions for protection and station control
Together with the SICAM power automation system, SIPROTEC 4 can be used with PROFIBUS DP. Over the low-cost electrical RS485 bus, or interference-free via the optical double ring, the units exchange information with the control system.
Units featuring IEC 60870-5-103 interfaces can be connected to SICAM in parallel via the RS485 bus or radially by fiber-optic link. Through this interface, the system is open for the connection of units of other manufacturers (see Fig. 7/49).
Because of the standardized interfaces, SIPROTEC units can also be integrated into systems of other manufacturers or in SIMATIC. Electrical RS485 or optical interfaces are available. The optimum physical data transfer medium can be chosen thanks to optoelectrical converters. Thus, the RS485 bus allows low-cost wiring in the cubicles and an interference-free optical connection to the master can be established.
For IEC 61850, an interoperable system solution is offered with SICAM PAS. Via the 100 Mbits/s Ethernet bus, the units are linked with PAS electrically or optically to the station PC. The interface is standardized, thus also enabling direct connection of units of other manufacturers to the Ethernet bus. With IEC 61850, however, the units can also be used in other manufacturers' systems (see Fig. 7/50).
Via modem and service interface, the protection engineer has access to the protection devices at all times. This permits remote maintenance and diagnosis (cyclic testing).
Parallel to this, local communication is possible, for example, during a major inspection.
Serial protection interface (R2R interface)
As an option, the 7SD52/53 provides one or two protection interfaces to cover two up to six line end applications in ring or chain topology and hot standby communication between two line ends.
In addition to the differential protection function, other protection functions can use this interface to increase selectivity and sensitivity as well as covering advanced applications.
·Fast phase-selective teleprotection signaling for distance protection, optionally with POTT or PUTT schemes
·Two and three-terminal line applications can be implemented without additional logic
·Signaling for directional ground(earth)- fault protection directional comparison for high-resistance faults in solidly grounded systems
·Echo function
·Interclose command transfer with the auto-reclosure "Adaptive dead time" (ADT) mode
·28 remote signals for fast transfer of binary signals
Flexible utilization of the communication channels by means of the programmable CFC logic

·FO61), OMA22) module: 820 nm fiber-optic interface/ST connectors for direct connection up to 3.5 km with multi-mode FO cable.
New fiber-optic interfaces, series FO1x ·FO171): For direct connection up to 24 km3), 1300 nm, for
mono-mode fiber 9/125 m, LC-Duplex connector ·FO181): For direct connection up to 60 km3), 1300 nm, for
mono-mode fiber 9/125 m, LC-Duplex connector ·FO191): For direct connection up to 100 km3), 1550 nm, for
mono-mode fiber 9/125 m, LC-Duplex connector
·FO30: 820 nm fiber-optic interface/ST connectors for direct connection up to 1.5 km and for connections to a IEEE C37.94 multiplexer interface.
The link to a multiplexed communication network is made by separate communication converters (7XV5662). These have a fiber-optic interface with 820 nm and 2 ST connectors to the protection relay. The link to the communication network is optionally an electrical X21 or a G703/-E1/-T1 interface. Furthermore the IEEE C37.94 interface is supported by the FO30 module.
For operation via copper wire communication (pilot wires or twisted telephone pair), a modern communication converter for copper cables is available. This operates with both the two-wire and three-wire copper connections which were used by conventional differential protection systems before. The communication converter for copper cables is designed for 5 kV insulation voltage. An additional 20 kV isolation transformer can extend the field of applications of this technique into ranges with higher insulation voltage requirements. The connection via FO cable to the relay is interference-free. With SIPROTEC 4 and the communication converter for copper cables a digital follow-up technique is available for two-wire protection systems (typical 8 km) and all three-wire protection systems using existing copper communication links.
Different communication converters are listed under "Accessories".
Communication data:
·32-bit CRC-check according to CCITT and ITU
·Each protection relay possesses a unique relay address
·Continuous communication link supervision: Individual faulty data telegrams do not constitute an immediate danger, if they occur only sporadically. The statistical availability, per minute and hour, of the serial protection interface can be displayed.
·Supported network interfaces X21/RS422 with 64 or 128 or 512 kbit/s; or G703-64 kbit/s and G703-E1 (2,048 kbit/s) or G703-T1 (1,554 kbit/s).
·Max. channel delay time 0.1 ms to 30 ms (in steps of 0.1 ms) or IEEE C37.94.
·Protocol HDLC

The protection interfaces have different options to cover new and existing communication infrastructures.
·FO51), OMA12) module: 820 nm fiber-optic interface with clock recovery/ST connectors for direct connection with multi-mode FO cable up to 1.5 km for the connection to a communication converter.

1) For flush-mounting housing. 2) For surface-mounting housing. 3) For surface-mounting housing the internal fiber-optic module
(OMA1) will be delivered together with an external repeater.

7/40 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD52/53
Communication
Communication possibilities between relays
1

Fig. 7/56 Direct optical link up to 1.5 km/3.5 km, 820nm

Fig. 7/57 Direct optical link up to 25/60 km with 1300 nm

or up to 100 km with 1550 nm

Fig. 7/58 Connection to a communication network CC-XG

7
Fig. 7/60 Connection to a communication network CC-2M
8

7SD52/53 7SD610 FO30
SIPV6.011en.eps

max. 1.5 km with 62.5 m/125 m multi-mode fiber
IEEE C37.94

MUX Communication network

FO30 with ST connectors

Fig. 7/59 Connection to a communication network via IEEE C37.94

Fig. 7/61 Connection to a pilot wire

9 10 11

15
Siemens SIP · Edition No. 8 7/41

Line Differential Protection / 7SD52/53
Typical connection

Typical connection

Typical connection for current and volt-

age transformers

3 phase current transformers with neutral

point in the line direction, I4 connected as summation current transformer (= 3I0):

Holmgreen circuit

3 voltage transformers, without connection

of the broken (open) delta winding on

the line side; the 3V0 voltage is derived

internally.

Note: Voltage inputs are always available in the

relay. But there is no need to connect it to

voltage transformers for the differential

protection function.
5

Fig. 7/62 Example of connection for current and voltage transformers

Alternative current measurement

The 3 phase current transformers are

connected in the usual manner. The neutral

point is in line direction. I4 is connected to

a separate neutral core-balance CT, thus permitting a high sensitive 3I0 measure-

ment.

Note:

Terminal Q7 of the I4 transformer must be connected to the terminal of the core-

balance CT pointing in the same direction

as the neutral point of the phase current

transformers (in this case in line direction).

The voltage connection is effected in

accordance with Fig. 7/62, 7/67 or 7/68.

Fig. 7/63 Alternative connection of current transformers for sensitive ground(earth)-current measuring with core-balance current transformers

15
7/42 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD52/53
Typical connection

Alternative current connection

3 phase current transformers with neutral point in the line direction, I4 connected to

a current transformer in the neutral point

of a grounded (earthed) transformer for

directional ground(earth)-fault protection. The voltage connection is effected in

accordance with Fig. 7/71, 7/76 or 7/77.

Fig. 7/64 Alternative connection of current transformers for measuring neutral current of a grounded (earthed) power transformer

Alternative current connection

3 phase current transformers with neutral

point in the line direction, I4 connected to

the summation current of the parallel line

for parallel line compensation on overhead

lines. The voltage connection is effected in

accordance with Fig. 7/71, 7/76 or 7/77.

Fig. 7/65 Alternative connection of current transformers for measuring the ground (earth) current of a parallel line

9 10

Fig. 7/66 Connection of current transformer with restricted ground-fault protection (REF)

14 15

Siemens SIP · Edition No. 8 7/43

Line Differential Protection / 7SD52/53
Typical connection

Alternative voltage connection

3 phase voltage transformers, V4 connected to broken (open) delta winding

(Ven) for additional summation voltage

monitoring and ground(earth)-fault direc-

tional protection. The current connection is effected in accordance with Fig. 7/62, 7/63,

7/64 and 7/65.

Fig. 6/67 Alternative connection of voltage transformers for measuring the displacement voltage (e-n voltage)

Alternative voltage connection

3 phase voltage transformers, V4 con-

nected to busbar voltage transformer for

synchrocheck.

Note:

Any phase-to-phase or phase-toground

(earth) voltage may be employed as the

busbar voltage. Parameterization is carried out on the unit. The current connection is

effected in accordance with Fig. 7/62, 7/63,

7/64 and 7/65.

10 11

Fig. 6/68 Alternative connection of voltage transformers for measuring the busbar voltage

15
7/44 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD52/53
Technical data

General unit data

Analog inputs

Rated frequency

50 or 60 Hz (selectable)

Rated current IN

1 or 5 A (selectable, controlled by firmware)

Rated voltage

80 to 125 V (selectable)

Power consumption
In CT circuits with IN = 1 A In CT circuits with IN = 5 A In VT circuits

Approx. 0.05 VA Approx. 0.30 VA Approx. 0.10 VA

Thermal overload capacity In CT circuits
In VT circuits

500 A for 1 s 150 A for 10 s 4 x IN continuous
230 V, continuous per phase

Dynamic overload capacity

In CT circuits

1250 A (half cycle)

In the CT circuit for high sensitive

ground-fault protection

(refer to ordering code)

Auxiliary voltage

Rated voltage

DC 24 to 48 V DC 60 to 125 V 1) DC 110 to 250 V 1) and AC 115 V with 50/60 Hz1)

Permissible tolerance

-20 % to +20 %

Max. superimposed AC voltage (peak-to-peak)

15 %

Power consumption During normal operation During pickup with all inputs and outputs activated

Approx. 8 W Approx. 18 W

Bridging time during auxiliary voltage failure Vaux AC/DC 110 V

50 ms

Binary inputs

Quantity Function can be assigned

8 or 16 or 24

Minimum permissible voltage

DC 19 or 88 or 176 V, bipolar

Range is selectable with jumpers (3 operating ranges)

for each binary input

Maximum permissible voltage

DC 300 V

Current consumption, energized Approx. 1.8 mA

Output relays

Quantity Function can be assigned

16 or 24 or 32

Switching capacity Make Break Break (for resistive load) Break (for = L/R 50 ms)

1000 W /VA 30 VA 40 W 25 VA

Switching voltage

250 V

Permissible current

30 A for 0.5 s 5 A continuous

LEDs

Quantity

RUN (green)

ERROR (red)

Indication (red), function can be 14 assigned

1) Ranges are settable by means of jumpers.

Unit design

Housing 7XP20 1/2 x 19" or 1/1 x 19"

See dimension drawings, part 14

Degree of protection acc. to EN 60529
Surface-mounting housing Flush-mounting housing
Rear Front

IP 51
IP 50 IP 51

For the terminals

IP 2x with cover cap

Weight Flush-mounting housing 1/2 x 19" 1/1 x 19"

6 kg 10 kg

Surface-mounting housing 1/2 x 19" 1/1 x 19"

11 kg 19 kg

Electrical tests

Specifications

Standards

IEC 60255 (product standards) ANSI/IEEE C37.90.0/.1/.2 UL 508 For further standards see "Individual functions"

Insulation tests

Standards

IEC 60255-5

Voltage test (100 % test) All circuits except for auxiliary supply, binary inputs and communication interfaces

2.5 kV (r.m.s.), 50/60 Hz

Auxiliary voltage and binary inputs (100 % test)

DC 3.5 kV

RS485/RS232 rear side communication interfaces and time synchronization interface (100 % test)

500 V (r.m.s.), 50/60 Hz

Impulse voltage test (type test) All circuits except for communication interfaces and time synchronization interface, class III

5 kV (peak); 1.2/50 s; 0.5 J 3 positive and 3 negative impulses at intervals of 5 s

EMC tests for noise immunity; type tests

Standards

IEC 60255-6, IEC 60255-22 (product standards) (type tests) EN 50082-2 (generic standard) DIN 57435 part 303

High frequency test IEC 60255-22-1, class III and VDE 0435 part 303, class III

2.5 kV (peak); 1 MHz; = 15 ms; 400 surges per s; test duration 2 s

Electrostatic discharge IEC 60255-22-2, class IV EN 61000-4-2, class IV
Irradiation with RF field, nonmodulated IEC 60255-22-3 (report), class III

8 kV contact discharge; 15 kV air discharge; both polarities; 150 pF; Ri = 330
10 V/m; 27 to 500 MHz

Irradiation with RF field, amplitude-modulated IEC 61000-4-3, class III

10 V/m; 80 to 1000 MHz; 80 % AM; 1 kHz

1 2 3 4 5 6 7 8 9 10 11 12 13

1) For flush-mounting housing. 2) For surface-mounting housing. 3) For surface-mounting housing the internal FO module OMA1
will be delivered together with an external repeater.

14 15

Siemens SIP · Edition No. 8 7/45

Line Differential Protection / 7SD52/53
Technical data

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Irradiation with RF field, pulsemodulated IEC 61000-4-3/ ENV 50204, class III

10 V/m; 900 MHz; repetition frequency 200 Hz; duty cycle 50 %

Fast transients, bursts IEC 60255-22-4 and IEC 61000-4-4, class IV

4 kV; 5/50 ns; 5 kHz; burst length = 15 ms; repetition rate 300 ms; both polarities; Ri = 50 ; test duration 1 min

High-energy surge voltages

(SURGE) IEC 61000-4-5, installati-

on class III Auxiliary supply

Common mode: 2 kV, 12 , 9 µF

Differential mode: 1 kV; 2 , 18 µF

Measurements inputs, binary inputs, binary outputs

Common mode: 2 kV, 42 , 0.5 µF Differential mode: 1 kV; 42 , 0.5 µF

Line-conducted HF, amplitude- 10 V; 150 kHz to 80 MHz; 80 % AM; modulated, IEC 61000-4-6, class III 1 kHz

Magnetic field with power frequency IEC 61000-4-8, class IV; IEC 60255-6

30 A/m continuous; 300 A/m for 3 s; 50 Hz; 0.5 mT; 50 MHz

Oscillatory surge withstand capability ANSI/IEEE C37.90.1

2.5 to 3 kV (peak); 1 to 1.5 MHz Damped wave; 50 surges per second; Duration 2 s; Ri = 150 to 200

Fast transient surge withstand capability, ANSI/IEEE C37.90.1

4 to 5 kV; 10/150 ns; 50 surges per second; both polarities; duration 2 s; Ri = 80

Radiated electromagnetic interfe- 35 V/m; 25 to 1000 MHz

rence, IEEE C37.90.2

amplitude and pulse-modulated

Damped oscillations IEC 60894, IEC 61000-4-12

2.5 kV (peak value), polarity alternating 100 kHz 1, 10 and 50 MHz, Ri = 200

EMC tests for interference emission; type tests

Standard

EN 50081-* (generic standard)

Conducted interference voltage on lines, only auxiliary supply, IEC-CISPR 22

150 kHz to 30 MHz Limit class B

Radio interference field strength 30 to 1000 MHz

IEC-CISPR 22

Limit class B

Mechanical dynamic tests

Vibration, shock stress and seismic vibration

During operation

Standards

IEC 60255-21 and IEC 60068-2

Vibration IEC 60255-21-1, class 2 IEC 60068-2-6

Sinusoidal 10 to 60 Hz: ± 0.075 mm amplitude; 60 to 150 Hz: 1 g acceleration frequency sweep 1 octave/min 20 cycles in 3 othogonal axes

Shock IEC 60255-21-2, class 1 IEC 60068-2-27

Half-sinusoidal acceleration 5 g, duration 11 ms, 3 shocks each in both directions of the 3 axes

Seismic vibration IEC 60255-21-2, class 1 IEC 60068-3-3

During transport Standards Vibration IEC 60255-21-1, class 2 IEC 60255-2-6
Shock IEC 60255-21-2, class 1 IEC 60068-2-27
Continuous shock IEC 60255-21-2, class 1 IEC 60068-2-29

IEC 60255-21 and IEC 60068-2
Sinusoidal 5 to 8 Hz: ± 7.5 mm amplitude; 8 to 150 Hz: 2 g acceleration frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes
Half-sinusoidal Acceleration 15 g, duration 11 ms, 3 shocks each in both directions of the 3 axes
Half-sinusoidal Acceleration 10 g, duration 16 ms, 1000 shocks each in both directions of the 3 axes

Climatic stress tests

Temperatures

Type-tested acc. to IEC 60068-2-1 -25 °C to +85 °C / -13 °F to +185 °F and -2, test Bd, for 16 h

Temporarily permissible operating -20 °C to +70 °C / -4 °F to +158 °F temperature, tested for 96 h

Recommended permanent operating temperature acc. to IEC 60255-6 (Legibility of display may be impaired above +55 °C / +131 °F)

-5 °C to +55 °C / +25 °F to +131 °F

Limiting temperature during permanent storage

-25 °C to +55 °C / -13 °F to 131 °F

Limiting temperature during transport

-25 °C to +70 °C / -13 °F to +158 °F

Humidity

Permissible humidity stress

Yearly average 75 % relative humi-

It is recommended to arrange the dity; on 56 days in the year up to

units in such a way, that they are 93 % relative humidity; condensation

not exposed to direct sunlight or is not permitted

pronounced temperature changes

that could cause condensation.

1) Ordering option with high-speed contacts required.

7/46 Siemens SIP · Edition No. 8

Futher information can be found in the current manual at: www.siemens.com/siprotec

Line Differential Protection / 7SD52/53
Selection and ordering data

Description 7SD5 combined multi-end line differential protection with distance protection
Device type1) Two-terminal differential relay with 4-line display Two-terminal differential relay with grapical display Multi-terminal differential relay with 4-line display Multi-terminal differential relay with graphical display

Measurement input Iph = 1 A2), Ie = 1 A2) Iph = 1 A2), Ie = high (min. = 0.005 A) Iph = 5 A2), Ie = 5 A2) Iph = 5 A2), Ie = sensitive (min. = 0.005 A)

Auxiliary voltage (Power supply, BI trigger level) 24 to 48 V DC, trigger level binary input 19 V4) 60 to 125 V DC3), trigger level binary input 19 V4) 110 to 250 V DC3), 115 V AC, trigger level binary input 88 V4) 220 to 250 V DC3), 115 V AC, trigger level binary input 176 V4)

Binary/ indication inputs

Signal/ command outputs incl. live status contact

Fast relay5)

Highspeed trip output6)

Housing width referred to 19"

Flushmounting housing/ screw-type terminals

Flushmounting housing/ plug-in terminals

Surfacemounting housing/ screw-type terminals

12 12

15 5

18 10

Region-specific default / language settings and function versions Region GE, German language (can be changed) Region world, English language (can be changed) Region US, US-English language (can be changed) Region world, French language (can be changed) Region world, Spanish language (can be changed) Region world, Italian language (can be changed)

Order No.

7SD5

2 2 32 23 33

1 2 5 6

2 4 5 6

Short code

see next page

G L

S D

P R

W
11

C D

1) Redundant prot. data interface for Hot-Standby-service is possible with a two terminal differential relay (second prot. data interface is needed)
2) Rated current 1/5 A can be selected by the means of jumpers.
3) Transition between three auxiliary voltage ranges can be selected by means of jumpers.

4) The binary input thresholds are selectable in three steps by means of jumpers.
5) Fast relays are indentified in the terminal diagram. The time advantage compared to signal/command outputs is approx. 3 ms, mainly for protection commands
6) High-speed trip outputs are identified in the in the terminal diagram. The time advantage compared to fast relays is approx. 5 ms

14 15

Siemens SIP · Edition No. 8 7/47

Line Differential Protection / 7SD52/53
Selection and ordering data

1 2 3 4 5 6 7 8 9 10

Description 7SD5 combined multi-end line differential protection with distance protection
System interfaces No system interface IEC protocol, electrical RS232 IEC protocol, electrical RS485 IEC protocol, optical 820 nm, ST-plug
Further protocols see supplement L
PROFIBUS DP slave, RS485 PROFIBUS DP slave, optical 820 nm, double ring, ST connector 1) DNP 3.0, RS485 DNP 3.0, optical 820 nm, ST connector 1) IEC 61850, 100 Mbit Etherrnet, electrical, double, RJ45 connector (EN100) IEC 61850, 100 Mbit Ethernet, with integrated switch, optical, double, LC-connector (EN100) 2)
DIGSI / Modem interface (on rear of device) and protection interface 1 See additional indication M
DIGSI / Modem interface (on rear of device) Without DIGSI-interface on rear DIGSI 4, electric RS232 DIGSI 4, electric RS485 DIGSI 4, optical 820 nm, ST plug
Protection data interface 1 FO5: Optical 820 nm, 2 ST-plugs, line length up to 1.5 km via multimode FO cable for communication converter or direct FO connection 3) FO6: Optical 820 nm, 2 ST-plugs, line length up to 3.5 km via multimode FO cable for direct FO connection FO17: Optical 1300 nm, LC-Duplex-plugs, line length up to 24 km via monomode FO cable for direct FO connection 4) FO18: Optical 1300 nm, LC-Duplex-plugs, line length up to 60 km via monomode FO cable for direct FO connection 4) 5) FO19: Optical 1550 nm, LC-Duplex-plugs, line length up to 100 km via monomode FO cable for direct FO connection 4) 6) FO30: Optical 820 nm, 2 ST-plugs, line length up to 1.5 km via multimode FO cable for communication networks with IEEE C37.94 interface or direct FO connection 7)

Order No. 7SD52 -

Short code

see next

page

L 0

A B G H R S

0 1 2 3

A B G H J
S

13 14 15

1) Not possible for surface mounting housing (Order No. pos. 9 = E/G/H/Q/R). For the surface mounted version, please order a device with the appropriate electrical RS485 interface and an external FO-converter
2) Not possible for surface mounting housing (Order No. pos. 9 = E/G/H/Q/R) please order the relay with electrical interface and use a separate fiber-optic switch.
3) Communication converter 7XV5662, see Accessories.
4) Device for surface mounting housing (Order No. pos. 9 = E/G/H/Q/R) will be delivered with external repeater 7XV5461-0Bx00.

5) For distances less than 25 km a set of optical attenuators 7XV5107-0AA00 must be installed to avoid saturation of the receiver element
6) For distances less than 50 km a set of optical attenuators 7XV5107-0AA00 must be installed to avoid saturation of the receiver element
7) Only available in flush-mounting housing (Order No. pos. 9 E/G/H/Q/R).

7/48 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD52/53
Selection and ordering data

Description 7SD5 combined multi-end line differential protection with distance protection

Functions 1 / Protection interface 2

Trip mode 3-pole 3-pole 1-/3-pole 1-/3-pole 3-pole 3-pole 1-/3-pole 1-/3-pole

Auto-reclosure (ANSI 79) without with without with without with without with

Synchro-check (ANSI 25) without without without without with with with with

Functions 1 and Protection interface 2 6)

Functions 1

Trip mode 3-pole 3-pole 1-/3-pole 1-/3-pole 3-pole 3-pole 1-/3-pole 1-/3-pole

Auto-reclosure (ANSI 79) without with without with without with without with

Synchro-check (ANSI 25) without without without without with with with with

Protection interface 2
FO5: Optical 820 nm, 2 ST-plugs, line length up to 1.5 km via multimode FO cable for communication converter or direct FO connection 1)
FO6: Optical 820 nm, 2 ST-plugs, line length up to 3.5 km via multimode FO cable for direct FO connection
FO17: Optical 1300 nm, LC-Duplex-plugs, line length up to 24 km via monomode FO cable for direct FO connection 2)
FO18: Optical 1300 nm, LC-Duplex-plugs, line length up to 60 km via monomode FO cable for direct FO connection 2) 3)
FO19: Optical 1550 nm, LC-Duplex-plugs, line length up to 100 km via monomode FO cable for direct FO connection 2) 4)
FO30: Optical 820 nm, 2 ST-plugs, line length up to 1.5 km via multimode FO cable for communication networks with IEEE C37.94 interface or direct FO connection 5)

Order No. 7SD52 -

Short code

0 see next 1 page

3 4

J
10
S

1) Communication converter 7XV5662, see Accessories.
2) Device for surface mounting housing (Order No. pos. 9 = E/G/H/Q/R) will be delivered with external repeater 7XV5461-0Bx00.
3) For distances less than 25 km a set of optical attenuators 7XV5107-0AA00 must be installed to avoid saturation of the receiver element.

4) For distances less than 50 km a set of optical attenuators 7XV5107-0AA00 must be installed to avoid saturation of the receiver element.
5) Only available in flush-mounting housing (Order No. pos. 9 E/G/H/Q/R).
6) In a two terminal differential relay the protection interface 2 can be used as redundant protection interface (Hot Standby).

14 15

Siemens SIP · Edition No. 8 7/49

Line Differential Protection / 7SD52/53
Selection and ordering data

1 2 3 4 5 6 7 8 9 10 11 12 13

Description 7SD5 combined multi-end line differential protection with distance protection

Order No. 7SD52 -

Functions
Time overcurrent protection/ Breaker failure protection (ANSI 50, 50N, 51, 51N, 50BF)

Ground fault protection (ANSI 67N)

with with with with with with with with with with

without without without with with with without without with with

Distance protection (Pickup Z<, polygon, MHO, parallel line comp.) Power swing detection (ANSI 21, 21N, 68, 68T) without without with without without with without without without without

Distance protection (Ipickup I>,-VI/, -Z<), polygon, parallel line comp. 2),
power swing det. (ANSI
21, 21N, 68, 68T)

Ground fault detection for isolated/ compensated networks 1)

without with without without with without without with without with

without without without without without without with with with with

Short code

C D E F G H J K L M

Additional functions 1
4 Remote commands/ 24 Remote indications

Transformer expansions

with with with with with with with with with with with with

without without without without with with with with with with with with

Fault locator
1-side measuring 1-side measuring 2-side measuring 2-side measuring 1-side measuring 1-side measuring 2-side measuring 2-side measuring 1-side measuring 1-side measuring 2-side measuring 2-side measuring

Voltage protection, frequence protection (ANSI 27, 50)

Restricted ground
fault low impedance (ANSI 87N) 2)

without

with

without

with

without

with

without

with

without

with

without

with

Additional functions 2

Measured values, extended, Min/Max values

External GPS synchronization

Capacitive current load compensation

without

with

without

with

without

with

without

with

without

with

without

with

1) Only available with Order No. Pos. 7 = 2 or 6 2) Only available with Order No. Pos. 7 = 1 or 5

7/50 Siemens SIP · Edition No. 8

Accessories

Line Differential Protection / 7SD52/53
Selection and ordering data

Description

Order No.

Opto-electric communication converter CC-XG (connection to communication network)

Converter to interface to X21 or RS422 or G703-64 kbit/s synchronous

communication interfaces

Connection via FO cable for 62.5 /125 m or 50 /120 m and

820 nm wavelength (multi-mode FO cable) with ST connector, max.

distance 1.5 km

Electrical connection via X21/RS422 or G703-64 kbit/s interface

7XV5662-0AA00

Opto-electric communication converter CC-2M to G703-E1 / -T1 communication networks with 2,048 /1,554 kbit/s
Converter to interface between optical 820 nm interface and G703-E1 /-T1 interface of a communication network Connection via FO cable for 62.5 /125 m or 50 /120 m and 820 nm wavelength (multi-mode FO cable) with ST connector,max. distance 1.5 km Electrical connection via G703-E1/-T1 interface

7XV5662-0AD00

Opto-electric communication converter (connection to pilot wire)
Converter to interface to a pilot wire or twisted telephone pair (typical 15 km length) Connection via FO cable for 62.5 /125 m or 50 /120 m and 820 nm wavelength (multi-mode FO cable) with ST connector; max. distance 1.5 km, screw-type terminals to pilot wire

7XV5662-0AC00

Additional interface modules
Protection interface mod. opt. 820 nm, multi-mode FO cable, ST connector, 1.5 km Protection interface mod. opt. 820 nm, multi-mode FO cable, ST connector, 3.5 km

C53207-A351-D651-1 C53207-A351-D652-1

Further modules
Protection interface mod. opt. 1300 nm, mono-mode FO cable, LC-Duplex connector, 24 km
Protection interface mod. opt. 1300 nm, mono-mode FO cable, LC-Duplex connector, 60 km
Protection interface mod. opt. 1550 nm, mono-mode FO cable, LC-Duplex connector, 100 km

C53207-A351-D655-1 C53207-A351-D656-1 C53207-A351-D657-1

Optical repeaters Serial repeater (2-channel), opt. 1300 nm, mono-mode FO cable, LC-Duplex connector, 24 km Serial repeater (2-channel), opt. 1300 nm, mono-mode FO cable, LC-Duplex connector, 60 km Serial repeater (2-channel), opt. 1550 nm, mono-mode FO cable, LC-Duplex connector, 100 km
Time synchronizing unit with GPS output GPS 1 sec pulse and time telegram IRIG B / DCF 77
Isolation transformer (20 kV) for pilot wire communication

7XV5461-0BG00 7XV5461-0BH00 7XV5461-0BJ00
7XV5664-0AA00 7XR9516

Voltage transformer miniature circuit-breaker
Rated current 1.6 A; thermal overload release 1.6 A; overcurrent trip 6 A

3RV1611-1AG14

1 2 3 4 5 6 7 8 9 10 11 12 13

15
Siemens SIP · Edition No. 8 7/51

Line Differential Protection / 7SD52/53
Selection and ordering data

Accessories
1
2
3

Description
Connecting cable Cable between PC / notebook (9-pin connector) and protection unit (9-pin connector) (contained in DIGSI 4, but can be ordered additionally)
Manual for 7SD522/523 V4.6 English

Order No.
7XV5100-4 C53000-G1176-C169

9 10 11 12 13 14 15

Fig. 7/69 Mounting rail for 19" rack

LSP2091-afp.eps

LSP2090-afp.eps

Fig. 7/70 2-pin connector

Fig. 7/71 3-pin connector

LSP2092-afp.eps

LSP2093-afp.eps

Fig. 7/72 Short-circuit link for current contacts

Fig. 7/73 Short-circuit link for voltage contacts/ indications contacts

LSP2289-afp.eps

Description

Order No.

Connector

2-pin 3-pin

C73334-A1-C35-1 C73334-A1-C36-1

Crimp connector
Crimping tool

CI2 0.5 to 1 mm2

0-827039-1 0-827396-1

CI2 0.5 to 2.5 mm2

0-827040-1 0-827397-1

Type III+ 0.75 to 1.5 mm2 0-163083-7 0-163084-2

For type III+ and matching female For CI2 and matching female

0-539635-1 0-539668-2 0-734372-1 1-734387-1

19"-mounting rail

C73165-A63-D200-1

Short-circuit For current terminals

links

For other terminals

C73334-A1-C33-1 C73334-A1-C34-1

Safety cover large for terminals small

C73334-A1-C31-1 C73334-A1-C32-1

Size of Supplier Fig. package

Siemens 7/70

Siemens 7/71

4000

Siemens 7/69

Siemens 7/72

Siemens 7/73

Siemens

1) Your local Siemens representative can inform you on local suppliers.

7/52 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD52/53
Connection diagram

Fig. 7/76 Additional setting by jumpers: Separation of common circuit of BO8 to BO12 with jumpers X80, X81, X82. Switching of BO14, BO15 as NO contact or NC contact with jumpers X41, X42, X43.
1) Configuration of binary outputs until Hardware-version /EE. For advanced flexibility see Fig. 7/76.
Fig. 7/74 Basic version in housing ½ x 19" with 8 binary inputs and 16 binary outputs
Fig. 7/75 Serial interfaces

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 7/53

Line Differential Protection / 7SD52/53
Connection diagram

Fig. 7/78 Additional setting by jumpers:

Separation of common circuit

of BO8 to BO12 with jumpers

X80, X81, X82. Switching of

BO14, BO15 as NO contact or NC contact with jumpers X41,

X42, X43.

*) For unit version 7SD52xx-xN/S/Q high-speed contacts
1) Configuration of binary outputs until Hardware-version /EE. For advanced flexibility see Fig. 7/78.

Fig. 7/77 Medium version in housing x 19"

7/54 Siemens SIP · Edition No. 8

Line Differential Protection / 7SD52/53
Connection diagram

Fig. 7/80 Additional setting by jumpers: Separation of common circuit of BO8 to BO12 with jumpers X80, X81, X82. Switching of BO14, BO15 as NO contact or NC contact with jumpers X41, X42, X43.
*) For unit version 7SD52xx-xR/P/T high-speed contacts 1) Configuration of binary outputs until Hardware-version /EE.
For advanced flexibility see Fig. 7/80. Fig. 7/79 Medium version in housing x 19"

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 7/55

Line Differential Protection / 7SD52/53
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
7/56 Siemens SIP · Edition No. 8

Transformer Differential Protection

Page

SIPROTEC 7UT6 differential protection relay

for transformers, generators, motors and busbars

8/3

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
8/2 Siemens SIP · Edition No. 8

Transformer Differential Protection / 7UT6
SIPROTEC 4 7UT6 differential protection relay for transformers, generators, motors and busbars

Function overview

·Differential protection for 2- up to 5-winding transformers

(3-/1-phase)

·Differential protection for motors and generators

·Differential protection for short 2 up to 5 terminal lines ·Differential protection for busbars up to 12 feeders

(phase-segregated or with summation CT)

LSP2456-afpen.tif

Fig. 8/1 SIPROTEC 7UT6 differential protection relay for ransformers, generators, motors and busbar
Description
The SIPROTEC 7UT6 differential protection relays are used for fast and selective fault clearing of short-circuits in transformers of all voltage levels and also in rotating electric machines like motors and generators, for short lines and busbars.
The protection relay can be parameterized for use with threephase and single-phase transformers.
The specific application can be chosen by parameterization. In this way an optimal adaptation of the relay to the protected object can be achieved.
In addition to the differential function, a backup overcurrent protection for 1 winding/star point is integrated in the relay. Optionally, a low or high-impedance restricted ground-fault protection, a negative-sequence protection and a breaker failure protection can be used. 7UT613 and 7UT633 feature 4 voltage inputs. With this option an overvoltage and undervoltage protection is available as well as frequency protection, reverse / forward power protection, fuse failure monitor and overexcitation protection. With external temperature monitoring boxes (thermo-boxes) temperatures can be measured and monitored in the relay. Therefore, complete thermal monitoring of a transformer is possible, e.g. hot-spot calculation of the oil temperature.
7UT613 and 7UT63x only feature full coverage of applications without external relays by the option of multiple protection functions e.g. overcurrent protection is available for each winding or measurement location of a transformer. Other functions are available twice: ground-fault differential protection, breaker failure protection and overload protection. Furthermore, up to 12 user-defined (flexible) protection functions may be activated by the customer with the choice of measured voltages, currents, power and frequency as input variables.

Protection functions ·Differential protection with phase-segregated measurement ·Sensitive measuring for low-fault currents ·Fast tripping for high-fault currents ·Restraint against inrush of transformer ·Phase /ground overcurrent protection ·Overload protection with or without temperature
measurement ·Negative-sequence protection ·Breaker failure protection ·Low/high-impedance restricted ground fault (REF) ·Voltage protection functions (7UT613/633)
Control functions ·Commands for control of circuit-breakers and isolators ·7UT63x: Graphic display shows position of switching elements,
local/remote switching by key-operated switch ·Control via keyboard, binary inputs, DIGSI 4 or SCADA system ·User-defined logic with CFC
Monitoring functions ·Self-supervision of the relay ·Trip circuit supervision ·Oscillographic fault recording ·Permanent differential and restraint current measurement,
extensive scope of operational values
Communication interfaces ·PC front port for setting with DIGSI 4 ·System interface
IEC 61850 Ethernet IEC 60870-5-103 protocol, PROFIBUS DP, MODBUS or DNP 3 ·Service interface for DIGSI 4 (modem)/ temperature monitoring (thermo-box) ·Time synchronization via IRIG-B/DCF 77

The relays provide easy-to-use local control and automation functions. The integrated programmable logic (CFC) allows the users to implement their own functions, e.g. for the automation of switchgear (interlocking). User-defined messages can be generated as well. The flexible communication interfaces are open for modem communication architectures with control system.

3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 8/3

Transformer Differential Protection / 7UT6
Application

1 2 3 4 5 6 7 8 9 10

Application
The numerical protection relays 7UT6 are primarily applied as differential protection on
transformers 7UT612: 2 windings 7UT613/633: 2 up to 3 windings 7UT635: 2 up to 5 windings,
generators motors short line sections small busbars parallel and series reactors.
The user selects the type of object that is to be protected by setting during configuration of the relay. Subsequently, only those parameters that are relevant for this particular protected object need to be set. This concept, whereby only those parameters relevant to a particular protected object need to be set, substantially contributed to a simplification of the setting procedure. Only a few parameters must be set. Therefore the new 7UT6 relays also make use of and extend this concept. Apart from the protected plant objects defined in the 7UT6, a further differential protection function allows the protection of
single busbars with up to 12 feeders.
The well-proven differential measuring algorithm of the 7UT51 relay is also used in the new relays, so that a similar response with regard to short-circuit detection, tripping time saturation detection and inrush restraint is achieved.

12 13

Fig. 8/2 Function diagram

15
8/4 Siemens SIP · Edition No. 8

Transformer Differential Protection / 7UT6
Application, construction

7UT612 7UT613/33 7UT635

Application Protection functions

ANSI No.

Three-phase Single-phase Autotransformer transformer trans-

Generator/ Busbar, Busbar,

Motor

3-phase 1-phase

former

Differential protection

87T/G/M/L

111

Ground-fault differential protection 87 N

122

Overcurrent-time protection, phases 50/51

133

Overcurrent-time protection 3I0

50/51N

Overcurrent-time protection, ground 50/51G

133 122

Overcurrent-time protection, single-phase

111

Negative-sequence protection

Overload protection IEC 60255-8

111 122

Overload protection IEC 60354

122

Overexcitation protection *) V/Hz 24

Overvoltage protection *) V>

Undervoltage protection *) V<

1 1

Frequency protection *) f>, f<

Reverse power protection *) -P

32R

Forward power protection*) P>, P< 32F

Fuse failure protection

60FL

1 1

Breaker failure protection

50 BF

122

External temperature monitoring 38

(thermo-box) Lockout

Measured-value supervision

Trip circuit supervision

74 TC

Direct coupling 1 Direct coupling 2

Operational measured values

Flexible protection functions

27, 32, 47, 12 12

Function applicable

50, 55, 59, 81

Function not applicable in this application

*) Only 7UT613/63x

Construction
The 7UT6 is available in three housing widths referred to a 19" module frame system. The height is 243 mm.
(7UT612), ½ (7UT613), (7UT633/635) of 19"
All cables can be connected with or without cable ring lugs. Plug-in terminals are available as an option, it is thus possible to employ prefabricated cable harnesses. In the case of surface mounting on a panel, the connection terminals are located above and below in the form of screw-type terminals. The communication interfaces are located on the same sides of the housing. For dimensions please refer to the dimension drawings (part 14).
Fig. 8/3 Rear view flush-mountig housing

LSP2236F.tif

11 12 13 14 15

Siemens SIP · Edition No. 8 8/5

Transformer Differential Protection / 7UT6
Protection functions

1 2 3 4 5 6 7 8 9 10 11

Protection functions

Differential protection for transformers (ANSI 87T)
When the 7UT6 is employed as fast and selective short-circuit protection for transformers the following properties apply:
·Tripping characteristic according to Fig. 8/4 with normal sensitive IDIFF> and high-set trip stage IDIFF>>
·Vector group and ratio adaptation
·Depending on the treatment of the transformer neutral point, zerosequence current conditioning can be set with or without consideration of the neutral current. With the 7UT6, the star-point current at the star-point CT can be measured and considered in the vector group treatment, which increases sensitivity by one third for single-phase faults.
·Fast clearance of heavy internal transformer faults with high-set differential element IDIFF>>.
·Restrain of inrush current with 2nd harmonic. Cross-block function that can be limited in time or switched off.
·Restrain against overfluxing with a choice of 3rd or 5th harmonic stabilization is only active up to a settable value for the fundamental component of the differential current.
·Additional restrain for an external fault with current transformer saturation (patented CT-saturation detector from 7UT51).
·Insensitivity to DC current and current transformer errors due to the freely programmable tripping characteristic and fundamental filtering.
·The differential protection function can be blocked externally by means of a binary input.

Fig. 8/4 Tripping characteristic with preset transformer parameters for three-phase faults Fig. 8/5 3-winding transformers (1 or 3-phase)

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8/6 Siemens SIP · Edition No. 8

Transformer Differential Protection / 7UT6
Protection functions

Sensitive protection by measurement of star-point current (see Fig. 8/6) (ANSI 87N/87GD)
Apart from the current inputs for detection of the phase currents on the sides of the protected object, the 7UT6 also contains normal sensitivity IE and high sensitivity IEE current measuring inputs. Measurement of the star-point current of an grounded winding via the normal sensitivity measuring input, and consideration of this current by the differential protection, increases the sensitivity during internal single-phase faults by 33 %. If the sum of the phase currents of a winding is compared with the star-point current measured with the normal sensitivity input IE, a sensitive ground current differential protection can be implemented (REF).
This function is substantially more sensitive than the differential protection during faults to ground in a winding, detecting fault currents as small as 10 % of the transformer rated current.
Furthermore, this relay contains a high-impedance differential protection input. The sum of the phase currents is compared with the star-point current. A voltage-dependent resistor (varistor) is applied in shunt (see Fig. 8/6). Via the sensitive current measuring input IEE, the voltage across the varistor is measured; in the milli-amp range via the external resistor. The varistor and the resistor are mounted externally. An ground fault results in a voltage across the varistor that is larger than the voltage resulting from normal current transformer errors. A prerequisite is the application of accurate current transformers of the class 5P (TPY) which exhibit a small measuring error in the operational and overcurrent range. These current transformers may not be the same as used for the differential protection, as the varistor may cause rapid saturation of this current transformers.
Both high-impedance and low-impedance REF are each available twice (option) for transformers with two grounded windings. Thus separate REF relays are not required.

Fig. 8/6 High-impedance differential protection

Differential protection for single-phase busbars (see Fig. 8/7) (ANSI 87L)
The short-circuit protection is characterized by the large number of current measuring inputs. The scope of busbar protection ranges from a few bays e.g. in conjunction with one and a half circuit-breaker applications, to large stations having up to more than 50 feeders. In particular in smaller stations, the busbar protection arrangements are too expensive. With the 7UT6 relays the current inputs may also be used to achieve a cost-effective busbar protection system for up to 12 feeders (Fig. 8/7). This busbar protection functions as a phase-selective protection with 1 or 5 A current transformers, whereby the protected phase is connected. All three phases can therefore be protected by applying three relays. Furthermore a single-phase protection can be implemented by connecting the three-phase currents via a summation transformer. The summation transformer connection has a rated current of 100 mA.
The selectivity of the protection can be improved by monitoring the current magnitude in all feeders, and only releasing the differential protection trip command when the overcurrent condition is also met. The security measures to prevent maloperation resulting from failures in the current transformer secondary circuits can be improved in this manner. This overcurrent release may also be used to implement a breaker failure protection. Should the release signal not reset within a settable time, this indicates that a breaker failure condition is present, as the short-circuit was not switched off by the bay circuit-breaker.

Fig. 8/7 Simple busbar protection with phase-selective configuration 7UT612: 7 feeders; 7UT613/633: 9 feeders; 7UT635: 12 feeders
Fig. 8/8 Generator/motor differential protection
After expiry of the time delay the circuit-breakers of the infeeds to the busbar may be tripped. Differential protection for generators and motors (see Fig. 8/8) (ANSI 87G/M) Equal conditions apply for generators, motors and series reactors. The protected zone is limited by the sets of current transfomers at each side of the protected object.

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Siemens SIP · Edition No. 8 8/7

Transformer Differential Protection / 7UT6
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13

Backup protection functions
Overcurrent-time protection (ANSI 50, 50N, 51, 51N)
Backup protection on the transformer is achieved with a twostage overcurrent protection for the phase currents and 3I0 for the calculated neutral current. This function may be configured for one of the sides or measurement locations of the protected object. The high-set stage is implemented as a definite-time stage, whereas the normal stage may have a definite-time or inverse-time characteristic. Optionally, IEC or ANSI characteristics may be selected for the inverse stage. The overcurrent protection 3I0 uses the calculated zero-sequence current of the configured side or measurement location. Multiple availability: 3 times (option)
Overcurrent-time protection for ground (ANSI 50 / 51G)
The 7UT6 feature a separate 2-stage overcurrent-time protection for the ground. As an option, an inverse-time characteristic according to IEC or ANSI is available. In this way, it is possible to protect e.g. a resistor in the transformer star point against thermal overload, in the event of a single-phase short-circuit not being cleared within the time permitted by the thermal rating. Multiple availability: 3 times (option)
Phase-balance current protection (ANSI 46) (Negative-sequence protection)
Furthermore a negative-sequence protection may be defined for one of the sides or measurement locations. This provides sensitive overcurrent protection in the event of asymmetrical faults in the transformer. The set pickup threshold may be smaller than the rated current.
Breaker failure protection (ANSI 50BF)
If a faulted portion of the electrical circuit is not disconnected upon issuing of a trip command, another command can be initiated using the breaker failure protection which operates the circuit-breaker, e.g., of an upstream (higher-level) protection relay. Multiple availability: 2 times (option)
Overexcitation protection Volt / Hertz (ANSI 24) (7UT613 / 633 only)
The overexcitation protection serves for detection of an unpermissible high induction (proportional to V/f) in generators or transformers, which leads to a thermal overloading. This may occur when starting up, shutting down under full load, with weak systems or under isolated operation. The inverse characteristic can be set via seven points derived from the manufacturer data. In addition, a definite-time alarm stage and an instantaneous stage can be used.

Trip circuit supervision (ANSI 74TC)
One or two binary inputs can be used for monitoring the circuitbreaker trip coil including its incoming cables. An alarm signal occurs whenever the circuit is interrupted.
Lockout (ANSI 86)
All binary outputs (alarm or trip relays) can be stored like LEDs and reset using the LED reset key. The lockout state is also stored in the event of supply voltage failure. Reclosure can only occur after the lockout state is reset.
External trip coupling
For recording and processing of external trip information via binary inputs. They are provided for information from the Buchholz relay or specific commands and act like a protective function. Each input initiates a fault event and can be individually delayed by a timer.
Undervoltage protection (ANSI 27) (7UT613/633 only)
The undervoltage protection evaluates the positive-sequence components of the voltages and compares them with the threshold values. There are two stages available.
The undervoltage function is used for asynchronous motors and pumped-storage stations and prevents the voltage-related instability of such machines. The function can also be used for monitoring purposes.
Overvoltage protection (ANSI 59) (7UT613/633 only)
This protection prevents insulation faults that result when the voltage is too high.
Either the maximum line-to-line voltages or the phase-to-ground voltages (for low-voltage generators) can be evaluated. The measuring results of the line-to-line voltages are independent of the neutral point displacement caused by ground faults. This function is implemented in two stages.
Frequency protection (ANSI 81) (7UT613 / 633 only)
The frequency protection prevents impermissible stress of the equipment (e.g. turbine) in case of under or overfrequency. It also serves as a monitoring and control element.
The function has four stages; the stages can be implemented either as underfrequency or overfrequency protection. Each stage can be delayed separately.
Even in the event of voltage distortion, the frequency measuring algorithm reliably identifies the fundamental waves and determines the frequency extremely precisely. Frequency measurement can be blocked by using an undervoltage stage.

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8/8 Siemens SIP · Edition No. 8

Transformer Differential Protection / 7UT6
Protection functions

Reverse-power protection (ANSI 32R) (7UT613/633 only)

The reverse-power protection monitors the direction of active power flow and picks up when the mechanical energy fails. This function can be used for operational shutdown (sequential tripping) of the generator but also prevents damage to the steam turbines. The reverse power is calculated from the positive-sequence systems of current and voltage. Asymmetrical power system faults therefore do not cause reduced measuring accuracy. The position of the emergency trip valve is injected as binary information and is used to switch between two trip command delays. When applied for motor protection, the sign (±) of the active power can be reversed via parameters.

Serial communication via RS485 bus or fiber-optic connection (possible with external converter

max. 6 temperatures

LSP2376-afp.tif

Forward-power protection (ANSI 32F)

(7UT613/633 only)

Fig. 8/9 Temperature measurement and monitoring with external thermo-boxes

Monitoring of the active power produced

by a generator can be useful for starting

up and shutting down generators. One stage monitors exceed- The ability of the 7UT6 to monitor the thermal condition can be

ing of a limit value, while another stage monitors falling below improved by serial connection of a temperature monitoring box

another limit value. The power is calculated using the positive- (also called thermo-box or RTD-box) (Fig. 8/9). The temperature

sequence component of current and voltage. The function can of up to 12 measuring points (connection of 2 boxes) can be

be used to shut down idling motors.

registered. The type of sensor (Pt100, Ni100, Ni120) can be

Flexible protection functions (7UT613/63x only)

selected individually for each measuring point. Two alarm stages are derived for each measuring point when the corresponding

For customer-specific solutions up to 12 flexible protection

set threshold is exceeded.

functions are available and can be parameterized. Voltages, currents, power and frequency from all measurement locations can be chosen as inputs. Each protection function has a settable threshold, delay time, blocking input and can be configured as a 1-phase or 3-phase unit.

Alternatively to the conventional overload protection, the relay can also provide a hot-spot calculation according to IEC 60345. The hot-spot calculation is carried out separately for each leg of the transformer and takes the different cooling modes of the transformer into consideration.

Monitoring functions
The relay comprises high-performance monitoring for the hardware and software.
The measuring circuits, analog-digital conversion, power supply voltages, battery, memories and software sequence (watch-dog) are all monitored.
The fuse failure function detects failure of the measuring voltage due to short-circuit or open circuit of the wiring or VT and avoids overfunction of the undervoltage elements in the protection functions. (7UT613/633 only)

The oil temperature must be registered via the thermo-box for the implementation of this function. An alarm warning stage and final alarm stage is issued when the maximum hot-spot temperature of the three legs exceeds the threshold value.
For each transformer leg a relative rate of ageing, based on the ageing at 98 °C is indicated as a measured value. This value can be used to determine the thermal condition and the current thermal reserve of each transformer leg. Based on this rate of ageing, a remaining thermal reserve is indicated in % for the hottest spot before the alarm warning and final alarm stage is reached.

Thermal monitoring of transformers
The importance of reducing the costs of transmitting and distributing energy by optimizing the system load has resulted in the increased importance of monitoring the thermal condition of transformers. This monitoring is one of the tasks of the monitoring systems, designed for medium and large transformers. Overload protection based on a simple thermal model, and using only the measured current for evaluation, has been integrated in differential protection systems for a number of years.

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Siemens SIP · Edition No. 8 8/9

Transformer Differential Protection / 7UT6
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Measured values

The operational measured values and statistic value registering in the 7UT6, apart from the registration of phase currents and voltages (7UT613/633 only) as primary and secondary values, comprises the following:

·Currents 3-phase IL1, IL2, IL3, I1, I2, 3I0 for each side and measurement location

·Currents 1-phase I1 to I12 for each feeder and further inputs Ix1 to Ix4

·Voltages 3-phase VL1, VL2, VL3, VL1L2, VL2L3, VL3L1, V1, V2, V0 and 1-phase VEN, V4

·Phase angles of all 3-phase / 1-phase currents and voltages

·Power Watts, Vars, VA/P, Q, S (P, Q: total and phase selective)

·Power factor (cos ),

·Frequency

·Energy + kWh, + kVarh, forward and reverse power flow

·Min./max. and mean values of VPH-PH, VPHE, VE, V0, V1, V2, IPH, I1, I2, 3I0, IDIFF, IRESTRAINT, S, P, Q, cos , f

Fig. 8/10 Commissioning via a standard Web browser: Phasor diagram

·Operating hours counter

·Registration of the interrupted currents and counter for protection trip commands

·Mean operating temperature of overload function

·Measured temperatures of external thermo-boxes

·Differential and restraint currents of differential protection and REF

LSP2821.tif

Metered values

For internal metering, the unit can calculate an energy metered value from the measured current and voltage values.

LSP2821.tif

The 7UT6 relays may be integrated into monitoring systems by means of the diverse communication options available in the relays. An example for this is the connection to the SITRAM transformer monitoring system with PROFIBUS DP interface.
Commissioning and operating aids

Fig. 8/11 Commissioning via a standard Web browser:Operating characteristic

Commissioning could hardly be easier and is fully supported by DIGSI 4. The status of the binary inputs can be read individually and the state of the binary outputs can be set individually. The operation of switching elements (circuit-breakers, disconnect devices) can be checked using the switching functions of the bay controller. The analog measured values are represented as wideranging operational measured values. To prevent transmission of information to the control center during maintenance, the bay controller communications can be disabled to prevent unnecessary data from being transmitted. During commissioning, all indications with test marking for test purposes can be connected to a control and protection system.

All measured currents and voltages (7UT613/633 only) of the transformer can be indicated as primary or secondary values. The differential protection bases its pickup thresholds on the rated currents of the transformer. The referred differential and stabilising (restraint) currents are available as measured values per phase.
If a thermo-box is connected, registered temperature values may also be displayed. To check the connection of the relay to the primary current and voltage transformers, a commissioning measurement is provided.

8/10 Siemens SIP · Edition No. 8

Transformer Differential Protection / 7UT6
Protection functions

This measurement function works with only 5 to 10 % of the transformer rated current and indicates the current and the angle between the currents and voltages (if voltages applied). Termination errors between the primary current transfomers and input transformers of the relay are easily detected in this manner.
The operating state of the protection may therefore be checked online at any time. The fault records of the relay contain the phase and ground currents as well as the calculated differential and restraint currents. The fault records of the 7UT613/633 relays also contain voltages.
Browser-based commissioning aid
The 7UT6 provides a commissioning and test program which runs under a standard internet browser and is therefore independent of the configuration software provided by the manufacturer.
For example, the correct vector group of the transformer may be checked. These values may be displayed graphically as vector diagrams.
The stability check in the operating characteristic is available as well as event log and trip log messages. Remote control can be used if the local front panel cannot be accessed.
Control and automation functions
Control
In addition to the protection functions, the SIPROTEC 4 units also support all control and monitoring functions that are required for operating medium-voltage or high-voltage substations.
The main application is reliable control of switching and other processes.
The status of primary equipment or auxiliary devices can be obtained from auxiliary contacts and communicated via binary inputs. Therefore it is possible to detect and indicate both the OPEN and CLOSED position or a fault or intermediate circuitbreaker or auxiliary contact position.
The switchgear or circuit-breaker can be controlled via: integrated operator panel binary inputs substation control and protection system DIGSI 4
Command processing
All the functionality of command processing is offered. This includes the processing of single and double commands with or without feedback, sophisticated monitoring of the control hardware and software, checking of the external process, control actions using functions such as runtime monitoring and automatic command termination after output. Here are some typical applications: ·Single and double commands using 1, 1 plus 1 common or 2
trip contacts ·User-definable bay interlocks ·Operating sequences combining several switching operations
such as control of circuit-breakers, disconnectors and grounding switches ·Triggering of switching operations, indications or alarm by combination with existing information

Automation / user-defined logic
With integrated logic, the user can set, via a graphic interface (CFC), specific functions for the automation of switchgear or substation. Functions are activated via function keys, binary input or via communication interface.
Switching authority
Switching authority is determined according to parameters, communication or by key-operated switch (when available).
If a source is set to "LOCAL", only local switching operations are possible. The following sequence of switching authority is laid down: "LOCAL"; DIGSI PC program, "REMOTE"
Every switching operation and change of breaker position is kept in the status indication memory. The switch command source, switching device, cause (i.e. spontaneous change or command) and result of a switching operation are retained.
Assignment of feedback to command
The positions of the circuit-breaker or switching devices and transformer taps are acquired by feedback. These indication inputs are logically assigned to the corresponding command outputs. The unit can therefore distinguish whether the indication change is a consequence of switching operation or whether it is a spontaneous change of state (intermediate position).
Chatter disable
The chatter disable feature evaluates whether, in a configured period of time, the number of status changes of indication input exceeds a specified figure. If exceeded, the indication input is blocked for a certain period, so that the event list will not record excessive operations.
Filter time
All binary indications can be subjected to a filter time (indication suppression).
Indication filtering and delay
Indications can be filtered or delayed.
Filtering serves to suppress brief changes in potential at the indication input. The indication is passed on only if the indication voltage is still present after a set period of time. In the event of indication delay, there is a wait for a preset time. The information is passed on only if the indication voltage is still present after this time.
Indication derivation
A further indication (or a command) can be derived from an existing indication. Group indications can also be formed. The volume of information to the system interface can thus be reduced and restricted to the most important signals.
Transmission lockout
A data transmission lockout can be activated, so as to prevent transfer of information to the control center during work on a circuit bay.
Test operation
During commissioning, all indications can be passed to an automatic control system for test purposes.

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 8/11

Transformer Differential Protection / 7UT6
Communication

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Communication

Rear-mounted interfaces
Two communication modules located on the rear of the unit incorporate optional equipment complements and readily permit retrofitting. They assure the ability to comply with the requirements of different communication interfaces.
The interfaces make provision for the following applications:
·Service interface (Port C/Port D) In the RS485 version, several protection units can be centrally operated with DIGSI 4. On connection of a modem, remote control is possible. Via this interface communication with thermo-boxes is executed.
·System interface (Port B) This interface is used to carry out communication with a control or protection and control system and supports a variety of communication protocols and interface designs, depending on the module connected.

Fig. 8/12 IEC 60870-5-103 star-type RS232 copper conductor connection or fiber-optic connection

Commissioning aid via a standard Web browser
In the case of the 7UT6, a PC with a standard browser can be connected to the local PC interface or to the service interface (refer to "Commissioning program"). The relays include a small Web server and send their HTML-pages to the browser via an established dial-up network connection.
Retrofitting: Modules for every type of communication
Communication modules for retrofitting are available for the entire SIPROTEC 4 unit range. These ensure that, where different communication interfaces (electrical or optical) and protocols (IEC 61850 Ethernet, IEC 60870-5-103, PROFIBUS DP, MODBUS RTU, DNP 3, DIGSI, etc.) are required, such demands can be met.

Fig. 8/13 Bus structure for station buswith Ethernet und IEC 61850, fiber-optic ring
Safe bus architecture ·RS485 bus
With this data transmission via copper conductors electromagnetic fault influences are largely eliminated by the use of twisted-pair conductor. Upon failure of a unit, the remaining system continues to operate without any disturbances.
·Fiber-optic double ring circuit The fiber-optic double ring circuit is immune to electromagnetic interference. Upon failure of a section between two units, the communication system continues to operate without disturbance.
It is generally impossible to communicate with a unit that has failed. If a unit were to fail, there is no effect on the communication with the rest of the system.

15
8/12 Siemens SIP · Edition No. 8

Transformer Differential Protection / 7UT6
Communication

IEC 61850 Ethernet

LSP2163-afpen.tif

The Ethernet-based IEC 61850 protocol is the worldwide standard for protection and control systems used by power supply

corporations. Siemens was the first manufacturer to support

this standard. By means of this protocol, information can also

be exchanged directly between bay units so as to set up simple masterless systems for bay and system interlocking. Access to

the units via the Ethernet bus is also possible with DIGSI.

IEC 60870-5-103

IEC 60870-5-103 is an internationally standardized protocol for

the efficient communication in the protected area.

IEC 60870-5-103 is supported by a number of protection device

manufacturers and is used worldwide. PROFIBUS DP

Fig. 8/14 RS232 / RS485 electrical communication module

LSP2162-afpen.tif

PROFIBUS DP is an industry-recognized standard for communica-

tions and is supported by a number of PLC and protection device manufacturers.

MODBUS RTU

MODBUS RTU is an industry-recognized standard for communications and is supported by a number of PLC and protection device

manufacturers.

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 2 compliant with DNP 3.0.

Fig. 8/15 820 nm fiber-optic communication module

DNP 3.0 is supported by a number of protection device manu-

facturers.

LSP2164-afp.tif LSP3.01-0021.tif

Fig. 8/16 PROFIBUS communication module, optical double-ring

10 11

Fig. 8/17 Optical Ethernet communication module for IEC 61850 with integrated Ethernet switch

Siemens SIP · Edition No. 8 8/13

Transformer Differential Protection / 7UT6
Communication

System solutions for protection and

station control Together with the SICAM power automa-

tion system, SIPROTEC 4 can be used

with PROFIBUS DP. Over the low-cost

electrical RS485 bus, or interference-free via the optical double ring, the units

exchange information with the control

system.

Units featuring IEC 60870-5-103 interfaces can be connected to SICAM in

parallel via the RS485 bus or radially by

fiber-optic link. Through this interface,

the system is open for the connection of units of other manufacturers

(see Fig. 8/12).

Because of the standardized interfaces,

SIPROTEC units can also be integrated into systems of other manufacturers or

in SIMATIC. Electrical RS485 or optical

interfaces are available. The optimum

physical data transfer medium can be chosen thanks to opto-electrical con-

verters. Thus, the RS485 bus allows

low-cost wiring in the cubicles and an

Fig. 8/18 System solution: Communications

interference-free optical connection to

the master can be established.

For IEC 61850, an interoperable system solution is offered with

SICAM PAS. Via the 100 Mbits/s Ethernet bus, the units are linked

with PAS electrically or optically to the station PC. The interface

is standardized, thus also enabling direct connection of units

of other manufacturers to the Ethernet bus. With IEC 61850,

however, the units can also be used in other manufacturers'

systems (see Fig. 8/13).
9

15
8/14 Siemens SIP · Edition No. 8

Transformer Differential Protection / 7UT6
Typical connections
Typical connections
1

Fig. 8/19 Standard connection to a transformer without neutral current measurement

Fig. 8/20 Connection to a transformer with neutral current measurement

10 11

15
Siemens SIP · Edition No. 8 8/15

Transformer Differential Protection / 7UT6
Typical connections

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
8/16 Siemens SIP · Edition No. 8

Fig. 8/21 Connection of transformer differential protection with high impedance REF (I8) and neutral current measurement at I7

Transformer Differential Protection / 7UT6
Typical connections

5
Fig. 8/22 Connection example to a single-phase power transformer with current transformer between starpoint and grounding point
6

Fig. 8/23 Connection example to a single-phase power transformer with only one current transformer (right side)

10 11

15
Siemens SIP · Edition No. 8 8/17

Transformer Differential Protection / 7UT6
Typical connections

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
8/18 Siemens SIP · Edition No. 8

Fig. 8/24 Connection to a three-phase auto-transformer with current transformer between starpoint and grounding point
Fig. 8/25 Generator or motor protection

Transformer Differential Protection / 7UT6
Typical connections

Fig. 8/26 Connection 7UT612 as single-phase busbar protection for 7 feeders, illustrated for phase L1

Fig. 8/27 Connection 7UT612 as busbar protection for feeders, connected via external summation current transformers (SCT) partial illustration for feeders 1, 2 and 7

14 15

Siemens SIP · Edition No. 8 8/19

Transformer Differential Protection / 7UT6
Typical connections

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
8/20 Siemens SIP · Edition No. 8

Fig. 8/28 Connection example 7UT613 for a three-winding power transformer

Transformer Differential Protection / 7UT6
Typical connections

Fig. 8/29 Connection example 7UT613 for a three-winding power transformer with current transformers between starpoint and grounding point, additional connection for high-impedance protection; IX3 connected as high-sensitivity input

12 13

15
Siemens SIP · Edition No. 8 8/21

Transformer Differential Protection / 7UT6
Typical connections

9 10

Fig. 8/30 Connection example 7UT613 for a three-phase auto-transformer with three-winding and current transformer between starpoint and grounding point

15
8/22 Siemens SIP · Edition No. 8

Transformer Differential Protection / 7UT6
Typical connections

Fig. 8/31 Connection example 7UT635 for a three-winding power transformer with 5 measurement locations (3-phase) and neutral current measurement

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 8/23

Transformer Differential Protection / 7UT6
Typical connections

3
Fig. 8/32 Voltage transformer connection to 3 star-connected voltage transformers (7UT613 and 7UT633 only)
4

Fig. 8/33 Voltage transformer connection to 3 star-connected voltage transformers with additional delta winding (e-n-winding) (7UT613 and 7UT633 only)

15
8/24 Siemens SIP · Edition No. 8

Transformer Differential Protection / 7UT6
Technical data

General unit data

Analog inputs

Rated frequency

50 or 60 Hz (selectable)

Rated current

0.1 or 1 or 5 A (selectable by jumper, 0.1 A)

Power consumption In CT circuits

7UT 612 613 633 635

with IN = 1 A; in VA approx. with IN = 5 A; in VA approx. with IN = 0.1 A; in VA approx. sensitive input; in VA approx.

0.02 0.2 0.001 0.05

0.05 0.3 0.001 0.05

Overload capacity In CT circuits Thermal (r.m.s.)
Dynamic (peak value) In CT circuits for highly sensitive input IEE
Thermal
Dynamic

IN
100 IN for 1 s 30 IN for 10 s 4 IN continuous 250 IN (half cycle)
300 A for 1 s 100 A for 10 s 15 A continuous 750 A (half cycle)

Rated voltage (7UT613/633 only) 80 to 125 V Power consumption per phase 0.1 VA at 100 V

Overload capacity Thermal (r.m.s.)

230 V continuous

Auxiliary voltage

Rated voltage

DC 24 to 48 V DC 60 to 125 V DC 110 to 250 V and AC 115 V (50/60 Hz), AC 230 V

Permissible tolerance

-20 to +20 %

Superimposed AC voltage (peak-to-peak)

15 %

Power consumption (DC/AC)

7UT 612 613 633 635

Quiescent; in W approx. Energized; in W approx. depending on design

6/12 6/12 6/12

12/19 20/28 20/28

Bridging time during failure of the auxiliary voltage
Vaux 110 V

50 ms

Binary inputs

Functions are freely assignable

Quantity marshallable

7UT 612 613 633 635

Rated voltage range

24 to 250 V, bipolar

Minimum pickup threshold

DC 19 or 88 V (bipolar)

Ranges are settable by means of

jumpers for each binary input

Maximum permissible voltage DC 300 V

Current consumption, energized Approx. 1.8 mA

Output relay

Command / indication / alarm relay

Quantity each with 1 NO contact

7UT 612 613 633 635

(marshallable)

1 alarm contact, with 1 NO or

NC contact (not marshallable)

Switching capacity Make Break Break (with resistive load) Break (with L/R w 50 ms)
Switching voltage Permissible total current
Operating time, approx. NO contact NO/NC contact (selectable) Fast NO contact High-speed*) NO trip outputs
LEDs
Quantity
RUN (green) ERROR (red) LED (red), function can be assigned
Unit design
Housing 7XP20
Degree of protection acc. to IEC 60529
For the device in surface-mounting housing in flush-mounting housing
front rear For personal safety Housing
Size, referred to 19" frame Weight, in kg Flush-mounting housing Surface-mounting housing

1000 W / VA 30 VA 40 W 25 W 250 V 30 A for 0.5 seconds 5 A continuous
8 ms 8 ms 5 ms < 1 ms
7UT 612 613 633 635 1 1 1 1 1 1 1 1 7 14 14 14
For dimensions please refer to dimension drawings part 14
IP 51
IP 51 IP 50 IP 2x with closed protection cover 7UT 612 613 633 635 1/3 1/2 1/1 1/1
5.1 8.7 13.8 14.5 9.6 13.5 22.0 22.7

Electrical tests Specifications
Standards
Insulation tests
Standards Voltage test (100 % test)
All circuits except for auxiliary supply, binary inputs and communication interfaces Auxiliary voltage and binary inputs (100 % test) RS485/RS232 rear side communication interfaces and time synchronization interface (100 % test) Impulse voltage test (type test) All circuits except for communication interfaces and time synchronization interface, class III

IEC 60255 (Product standards) ANSI/IEEE C37.90.0/.1/.2 UL 508
EC 60255-5 and 60870-2-1 2.5 kV (r.m.s.), 50 Hz / 60 Hz
DC 3.5 kV 500 V (r.m.s.), 50 Hz / 60 Hz
5 kV (peak); 1.2/50 ms; 0.5 J 3 positive and 3 negative impulses at intervals of 5 s

1 2 3 4 5 6 7 8 9 10 11 12 13 14

*) With high-speed contacts all operating times are reduced by 4.5 ms.

Siemens SIP · Edition No. 8 8/25

Transformer Differential Protection / 7UT6
Technical data

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Electrical tests (cont'd)

EMC tests for interference immunity

Standards

IEC 60255-6, 60255-22 (product standards) EN 6100-6-2 (generic standard) DIN 57435 / Part 303

High frequency test IEC 60255-22-1, class III and DIN 57435 / Part 303, class III
Electrostatic discharge IEC 60255-22-2 class IV EN 61000-4-2, class IV
Irradiation with RF field, frequency sweep, IEC 60255-22-3, IEC 61000-4-3 class III

2.5 kV (peak); 1 MHz; = 15 ms; 400 surges per s; test duration 2 s; Ri = 200
8 kV contact discharge; 15 kV air discharge; both polarities; 150 pF; Ri = 330
10 V/m; 80 to 1000 MHz; 80 % AM; 1 kHZ

Irradiation with RF field, amplitude- 10 V/m; 80, 160, 450, 900 MHz,

modulated, single frequencies,

80 % AM;

IEC 60255-22-3,

duration > 10 s

IEC 61000-4-3, class III

Irradiation with RF field, pulsemodulated, single frequencies, IEC 60255-22-3, IEC 61000-4-3/ ENV 50204, class III

10 V/m; 900 MHz; repetition frequency 200 Hz; duty cycle 50 % PM

Fast transients interference, bursts IEC 60255-22-4 and IEC 61000-4-4, class IV
High-energy surge voltages (SURGE), IEC 61000-4-5, installation class III

4 kV; 5/50 ns; 5 kHz; burst length = 15 ms; repetition rate 300 ms; both polarities; Ri = 50 ; test duration 1 min
Impulse: 1.2/50 ms

Auxiliary supply

Analog inputs, binary inputs, binary outputs
Line-conducted HF, amplitudemodulated IEC 61000-4-6, class III

Common (longitudinal) mode: 2kV; 12 , 9 F Differential (transversal) mode: 1kV; 2 , 18 F
Common (longitude) mode: 2kV; 42 , 0.5 F Differential (transversal) mode: 1kV; 42 , 0.5 F
10 V; 150 kHz to 80 MHz; 80 % AM; 1 kHz

EMC tests for interference immunity (cont'd)

Magnetic field with power

30 A/m continuous; 300 A/m for

frequency

3 s; 50 Hz, 0.5 mT; 50 Hz

IEC 61000-4-8, IEC 60255-6 class IV

Oscillatory surge withstand capability, ANSI/IEEE C37.90.1
Fast transient surge withstand capability, ANSI/IEEE C37.90.1
Damped oscillations IEC 60894, IEC 61000-4-12

2.5 kV (peak); 1 MHz; = 15 s; Damped wave; 400 surges per second; duration 2 s; Ri = 200
4 kV; 5/50 ns; 5 kHz; burst 15 ms; repetition rate 300 ms; both polarities; duration 1 min.; Ri = 80
2.5 kV (peak value), polarity alternating 100 kHz, 1 MHz, 10 MHz and 50 MHz, Ri = 200

EMC tests for interference emission (type test)

Standard

EN 50081-* (generic standard)

Conducted interference, only auxiliary supply IEC-CISPR 22

150 kHz to 30 MHz Limit class B

Radio interference field strenght IEC-CISPR 22

30 to 1000 MHz Limit class B

Mechanical stress tests

Vibration, shock stress and seismic vibration

During operation

Standards

IEC 60255-21 and IEC 60068

Vibration IEC 60255-21-1, class 2 IEC 60068-2-6

Sinusoidal 10 to 60 Hz: ± 0.075 mm amplitude; 60 to 150 Hz: 1 g acceleration frequency sweep 1 octave/min. 20 cycles in 3 orthogonal axes

Shock IEC 60255-21-2, class 1 IEC 60068-2-27

Half-sinusoidal acceleration 5 g, duration 11 ms, 3 shocks each in both directions of the 3 axes

Seismic vibration IEC 60255-21-2, class 1 IEC 60068-3-3

During transport

Standards

IEC 60255-21 and IEC 60068

Vibration IEC 60255-21-1, class 2 IEC 60255-2-6

Sinusoidal 5 to 8 Hz: ± 7.5 mm amplitude; 8 to 150 Hz: 2 g acceleration frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes

Shock IEC 60255-21-2, class 1 IEC 60068-2-27

Half-sinusoidal acceleration 15 g, duration 11 ms, 3 shocks each in both directions of the 3 axes

Continuous shock IEC 60255-21-2, class 1 IEC 60068-2-29

Half-sinusoidal acceleration 10 g, duration 16 ms, 1000 shocks on each of the 3 axes in both directions

Climatic stress tests
Temperatures
Type-tested acc. to IEC 60068-2-1 and -2, test Bd, for 16 h
Temporarily permissible operating temperature, tested for 96 h
Recommended permanent operating temperature acc. to IEC 60255-6 (Legibility of display may be impaired above +55 °C / +131 °F) Limiting temperature during
permanent storage Limiting temperature during-
transport
Humidity
Permissible humidity stress It is recommended to arrange the units in such a way that they are not exposed to direct sunlight or pronounced temperature changes that could cause condensation.

-25 °C to +85 °C / -13 °F to +185 °F -20 °C to +70 °C / -4 °F to +158 °F -5 °C to +55 °C / +25 °F to +131 °F
-25 °C to +55 °C / -13 °F to +131 °F -25 °C to +70 °C / -13 °F to +158 °F
Yearly average 75 % relative humidity; on 56 days in the year up to 93 % relative humidity; ondensation not permitted

Futher information can be found in the current manual at: www.siemens.com/siprotec

8/26 Siemens SIP · Edition No. 8

Transformer Differential Protection / 7UT6
Selection and ordering data

Description 7UT612 differential protection relay for transformers, generators, motors and busbars Housing x 19"; 3 BI, 4 BO, 1 live status contact, 7 I, IEE
Rated current IN = 1 A IN = 5 A
Rated auxiliary voltage (power supply, binary inputs) DC 24 to 48 V, binary input threshold 19 V2) DC 60 to 125 V1), binary input threshold 19 V2) DC 110 to 250 V1), AC 115/230 V, binary input threshold 88 V2) DC 220 to 250 V1), AC 115/230 V, binary input threshold 176 V1,2,3)
Unit design For panel surface mounting, two-tier terminals on top and bottom For panel flush mounting, plug-in terminals (2/3-pole AMP connector) For panel flush mounting, screw-type terminals, (direct wiring/ring lugs)
Region-specific default settings/function and language settings Region DE, 50/60 Hz, IEC/ANSI, language German; selectable Region World, 50/60 Hz, IEC/ANSI, language English (GB); selectable Region US, 60/50 Hz, ANSI/IEC, language English (US); selectable Region World, 50/60 Hz, IEC/ANSI, language Spanish; selectable
System interface (Port B ) on rear No system interface IEC 60870-5-103 protocol, electrical RS232 IEC 60870-5-103 protocol, electrical RS485 IEC 60870-5-103 protocol, optical 820 nm, ST connector PROFIBUS DP Slave, electrical RS485 PROFIBUS DP Slave, optical 820 nm, double loop, ST connector4) MODBUS, electrical RS485 MODBUS, optical 820 nm, ST connector4) DNP 3.0, electrical RS485 DNP 3.0, optical 820 nm, ST connector4) IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector (EN 100) IEC 61850, 100 Mbit Ethernet, optical, double, LC connector (EN 100)5)

Order No. 7UT612 -

Order code

- A0-

1 5
2 4 5 6

see next page

B D E

A B C E

L 0A

L 0 B

L 0D

L 0 E

L 0G

L 0H

L 0 R

L 0 S

2 3 4 5 6 7 8 9 10

1) With plug-in jumper one of the 2 voltage ranges can be selected 2) For each binary input one of 2 pick-up threshold ranges can be
selected with plug-in jumper 3) Ordering option 6 only for V4.6 and higher

4) Not possible with surface mounting housing (position 9 = B). For the surface mounted version, please order a device with the appropriate electrical RS485 interface and accessories as stated in A.1under ,,External converters"
5) Cannot be delivered in connection with 9th digit = B.

14 15

Siemens SIP · Edition No. 8 8/27

Transformer Differential Protection / 7UT6
Selection and ordering data

Description

Order No.

Order code

7UT612 differential protection relay for transformers, generators, motors and busbars

7UT612 -

DIGSI 4 / browser / modem interface (Port C) on rear/temperature monitoring box connection

- A0

No DIGSI 4 port

DIGSI 4 / browser, electrical RS232 DIGSI 4 / browser or temperature monitoring box, electrical RS485

1 2

DIGSI 4 / browser or temperature monitoring box, 820 nm fiber optic, ST connector

Functions

Measured values/monitoring functions

Basic measured values

Basic measured values, transformer monitoring functions

(connection to thermo-box/hot spot acc. to IEC, overload factor)1)

Differential protection + basic functions

Differential protection for transformer, generator, motor, busbar (87)

Overload protection for one winding (49), Lockout (86)

Overcurrent-time protection (50/51): I>, I>>, IP (inrush stabilization)

Overcurrent-time protection (50N/51N): 3I0>, 3I0>>, 3I0P (inrush stabilization) Overcurrent-time protection ground (50G/51G): IE>, IE>>, IEP (inrush stabilization)

Differential protection + basic functions + additional functions

Restricted ground fault protection, low impedance (87N)

Restricted ground fault protection, high impedance (87N without resistor and varistor), O/C 1-phase Trip circuit supervision (74TC), breaker failure protection (50BF), unbalanced load protection (46)

1) Only in connection with position 12 = 2 or 3

8/28 Siemens SIP · Edition No. 8

Transformer Differential Protection / 7UT6
Selection and ordering data

Description 7UT613 differential protection relay for transformers, generators, motors and busbars Housing ½ x19"; 5 BI, 8 BO, 1 live status contact, 11 I, IEE1)
Rated current IN = 1 A IN = 5 A
Rated auxiliary voltage (power supply, binary inputs) DC 24 to 48 V, binary input threshold 19 V2) DC 60 to 125 V1), binary input threshold 19 V2) DC 110 to 250 V1), AC 115/230 V, binary input threshold 88 V2) DC 220 to 250 V1), AC 115/230 V, binary input threshold 176 V1,2)
Unit design Surface mounting housing with two-tier terminals, ½ x 19", 5 BI, 8 BO, 1 live status contact Flush mounting housing, ½ x 19", with plug-in terminals, 5 BI, 8 BO, 1 live status contact Flush mounting housing with screwed terminals, ½ x 19", 5 BI, 8 BO, 1 live status contact
Region-specific default settings/language settings Region DE, 50/60 Hz, IEC/ANSI, language German; selectable Region World, 50/60 Hz, IEC/ANSI, language English (GB); selectable Region US, 60/50 Hz, ANSI/IEC, language English (US); selectable Region World, 50/60 Hz, IEC/ANSI, language French; selectable Region World, 50/60 Hz, IEC/ANSI, language Spanish; selectable
System interface (Port B ) on rear No system interface IEC 60870-5-103 protocol, electrical RS232 IEC 60870-5-103 protocol, electrical RS485 IEC 60870-5-103 protocol, optical 820 nm, ST connector PROFIBUS DP Slave, electrical RS485 PROFIBUS DP Slave, optical 820 nm, double ring, ST connector3) MODBUS, electrical RS485 MODBUS, optical 820 nm, ST connector4) DNP 3.0, electrical RS485 DNP 3.0, optical 820 nm, ST connector4) IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector IEC 61850, 100 Mbit Etherent, optical, ST-connector4)

Order No. 7UT613 -

Order code

see next page

2 4 5 6

B D E

A B C D E

L 0A

L 0 B

L 0D

L 0 E

L 0G

L 0H

L 0 R

L 0 S

2 3 4 5 6 7 8 9 10

1) One of the 2 voltage ranges can be selected with plug-in jumper
2) For each binary input one of 2 pick-up threshold ranges can be selected with plug-in jumper.

3) Not possible with surface mounting housing (position 9 = B). For the surface mounted version, please order a device with the appropriate electrical RS485 interface and accessories in accordance with A.1 under ,,External Converters"
4) Cannot be delivered in connection with 9th digit = B.

14 15

Siemens SIP · Edition No. 8 8/29

Transformer Differential Protection / 7UT6
Selection and ordering data

1 2 3 4 5 6 7 8 9 10 11 12 13

Description 7UT613 differential protection relay for transformers, generators, motors and busbars
Port C and Port D Port C: DIGSI 4 / modem, electrical RS232; Port D: empty Port C: DIGSI 4 / modem/thermo-box, electrical RS485; Port D: empty Port C and Port D installed
Port C (service interface) DIGSI 4 / modem, electrical RS232 DIGSI 4 / modem/thermo-box, electrical RS485
Port D (additional interface) Thermo-box, optical 820 nm, ST connector1) Thermo-box, electrical RS485
Measured values /monitoring functions Basic measured values Extended measured values, min./max. values, mean values Extended measured values, min./max., mean values, transformer monitoring functions (connection to thermo-box/hot spot, overload factor)2)
Differential protection + basic functions Differential protection for transformer, generator, motor, busbar (87) Overload protection according to IEC for one side (49) Lock out (86) Overcurrent-time protection phases (50/51): I>, I>>, IP (inrush stabilization) Overcurrent-time protection 3I0 (50N/51N): 3I0>, 3I0>>, 3I0P (inrush stabilization) Overcurrent-time protection ground (50G/51G): IE>, IE>>, IEP (inrush stabilization)
Differential protection + basic functions + additional current functions Restricted ground-fault protection, low impedance (87N) Restricted ground-fault protection, high impedance (87N without resistor and varistor), O/C 1-phase Trip circuit supervision (74TC) Unbalanced load protection (46) Breaker failure protection (50BF) High-sensitivity overcurrent-time protection/tank leakage protection (64), O/C 1-phase
Additional voltage functions Without voltage functions With overexcitation protection and voltage/power/energy/measurement With overexcitation protection and voltage/power/energy measurement + Over/undervoltage protection (59/27) + Frequency protection (81) + Directional power protection (32R/F) + Fuse failure monitor (60FL)
Additional functions (general) Without Multiple protection functions (50, 51, 50N/G, 87N, 50BF, 49)1) Flexible protection functions Multiple + flexible protection functions

Order No. 7UT613 -

Order code

1 2

A F

1 2
4

B
A B
C
0 1 2 3

1) In case of a connection to a RTD box 7XV5662-xAD10, a RS485-LWL converter 7XV5650-0xA00 is required.

2) Only in connection with position 12 = 2 or 9 and Mxx (supplementary)

8/30 Siemens SIP · Edition No. 8

Transformer Differential Protection / 7UT6
Selection and ordering data

Description
7UT63 differential protection relay for transformers, generators,motors and busbars, graphic display
Housing, inputs and outputs Housing x 19", 21 BI, 24 BO, 1 live status contact, 12 current inputs (11 I, IEE); 4 voltage inputs (1 x 3-phase + 1 x 1-phase) Housing x 19", 29 BI, 24 BO, 1 live status contact, 16 current inputs (14 I, 2 IEE)
Rated current IN = 1 A IN = 5 A
Rated auxiliary voltage (power supply, binary inputs) DC 24 to 48 V, binary input threshold 19 V2) DC 60 to 125 V 1), binary input threshold 19 V2) DC 110 to 250 V 1), AC 115/230 V, binary input threshold 88 V2) DC 220 to 250 V 1), AC 115/230 V, binary input threshold 176 V2)
Unit design Surface-mounting with two-tier terminals Flush-mounting with plug-in terminals Flush-mounting with screw-type terminals Surface-mounting with two-tier terminals, with 5 high-speed trip contacts Flush-mounting with plug-in terminals, with 5 high-speed trip contacts Flush-mounting with screw-type terminals, with 5 high-speed trip contacts
Region-specific default settings/language settings Region DE, 50/60 Hz, IEC/ANSI language German; selectable Region World, 50/60 Hz, IEC/ANSI language English (GB); selectable Region US, 60/50 Hz, ANSI/IEC language English (US); selectable Region World, 50/60 Hz, IEC/ANSI, language French; selectable Region World, 50/60 Hz, IEC/ANSI language Spanish; selectable
System interface (Port B ) on rear No system interface IEC 60870-5-103 protocol, electrical RS232 IEC 60870-5-103 protocol, electrical RS485 IEC 60870-5-103 protocol, optical 820 nm, ST connector PROFIBUS DP Slave, electrical RS485 PROFIBUS DP Slave, optical 820, double ring, ST connector3) MODBUS, electrical RS485 MODBUS, optical 820 nm, ST connector4) DNP 3.0, electrical RS485 DNP 3.0, optical 820 nm, ST connector4) IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector (EN 100) IEC 61850, 100 Mbit Ethernet, optical, LC-connector4)

Order No. 7UT63 -

Order code

see next page

1 5

2 4 5 6

B D E N P Q

A B C D E

L 0A

L 0 B

L 0D

L 0 E

L 0G

L 0H

L 0 R

L 0 S

2 3 4 5 6 7 8 9 10 11 12

1) One of the 2 voltage ranges can be selected with plug-in jumper
2) For each binary input one of 2 pick-up threshold ranges can be selected with plug-in jumper

3) Not possible with surface mounting housing (position 9 = B). For the surface mounted version, please order a device with the appropriate electrical RS485 interface and accessories in accordance with A. under ,,External Converters"
4) Cannot be delivered in connection with 9th digit = B.

14 15

Siemens SIP · Edition No. 8 8/31

Transformer Differential Protection / 7UT6
Selection and ordering data

1 2 3 4 5 6 7 8 9 10 11 12

Description
7UT63 differential protection relay for transformers, generators,motors and busbars, graphic display
Port C and Port D Port C: DIGSI 4/modem, electrical RS232; Port D: empty Port C: DIGSI 4/modem/thermo-box, electrical RS485; Port D: empty Port C and Port D installed
Port C (service interface) DIGSI 4/modem, electrical RS232 DIGSI 4/modem/thermo-box, electrical RS485
Port D (additional interface) Thermo-box, optical 820 nm, ST connector1) Thermo-box, electrical RS485
Measured values/monitoring functions Basic measured values Extended measured values, min./max. values, mean values Extended measured values, min./max. values, mean values, transformer monitoring functions (connection to thermo-box/hot spot, overload factor)2)
Differential protection + basic functions Differential protection for transformer, generator, motor, busbar (87) Overload protection according to IEC for one side (49) Lock out (86) Overcurrent-time protection phases (50/51): I>, I>>, IP (inrush stabilization) Overcurrent-time protection 3I0 (50N/51N): 3I0>, 3I0>>, 3I0P (inrush stabilization) Overcurrent-time protection ground (50G/51G): IE>, IE>>, IEP (inrush stabilization)
Differential protection + basic functions + additional current functions Restricted ground-fault protection, low impedance (87N) Restricted ground-fault protection, high impedance (87N without resistor and varistor), O/C 1-phase Trip circuit supervision (74TC) Unbalanced load protection (46) Breaker failure protection (50BF) High-sensitivity overcurrent-time protection/tank leakage protection (64), O/C 1-phase
Additional voltage functions (only with 7UT633) Without voltage functions With overexcitation protection and voltage/power/energy/measurement With overexcitation protection and voltage/power/energy measurement + Over/undervoltage protection (59/27) + Frequency protection (81) + Directional power protection (32R/F) + Fuse failure monitor (6FL)
Additional functions (general) Without Multiple protection functions (50, 51, 50N/G, 87N, 50BF, 49)3) Flexible protection functions Multiple + flexible protection functions

Order No. 7UT63 -

Order code

1 2 9
1 2 4

M
1 2
A F

B
A B
C
0 1 2 3

14 15

1) In case of a connection to a RTD box 7XV5662-xAD10, a RS485-LWL converter 7XV5650-0xA00 is required.
2) Only in connection with position 12 = 2 or 9 and Mxx (supplementary)

3) Available if selected on position 14.

8/32 Siemens SIP · Edition No. 8

Transformer Differential Protection / 7UT6
Selection and ordering data

Accessories

LSP2289-afp.eps

Accessories
Fig. 8/34 Mounting rail for 19" rack

LSP2090-afp.eps

Fig. 8/35 2-pin connector

Fig. 8/36 3-pin connector

LSP2091-afp.eps

Description

Order No.

Connecting cable

Cable between PC/notebook (9-pin connector)

and protection relay (9-pin connector)

(contained in DIGSI 4, but can be ordered additionally)

7XV5100-4

Cable between thermo-box and relay - length 5 m / 16.4 ft

7XV5103-7AA05

- length 25 m / 82 ft

7XV5103-7AA25

- length 50 m / 164 ft

7XV5103-7AA50

Voltage transformer miniature circuit-breaker Rated current 1.6 A;

thermal overload release 1.6 A;

overcurrent trip 6 A

3RV1611-1AG14

Temperature monitoring box with 6 thermal inputs

For SIPROTEC units

With 6 temperature sensors and

AC/DC 24 to 60 V

7XV5662-2AD10

RS485 interface

AC/DC 90 to 240 V 7XV5662-5AD10

Manual for 7UT6x English V4.6

5
C53000-G1176-C230-2

German V4.6

C53000-G1100-C230-3

Turkey V4.6 Manual for 7UT612

C53000-G115A-C230-1
6

English

C53000-G1176-C148-1

Manual for 7UT6 English V4.0 English V4.6

C53000-G1176-C160-1

C53000-G1176-C160-2

Description

Connector

2-pin 3-pin

Order No.
C73334-A1-C35-1 C73334-A1-C36-1

Size of Supplier Fig. package

Siemens 8/35

Siemens 8/36

Crimp connector
Crimping tool

CI2 0.5 to 1 mm2
CI2 0.5 to 2.5 mm2
Type III+ 0.75 to 1.5 mm2
For type III+ and matching female For CI2 and matching female

0-827039-1 0-827396-1
0-827040-1 0-827397-1
0-163083-7 0-163084-2
0-539635-1 0-539668-2 0-734372-1 1-734387-1

19"-mounting rail

C73165-A63-D200-1

Short-circuit For current terminals

links

For other terminals

C73334-A1-C33-1 C73334-A1-C34-1

Safety cover large for terminals small

C73334-A1-C31-1 C73334-A1-C32-1

4000 1 4000 1 4000 1 1
1
1
1 1
1 1

1) 1) 1) 1) 1) 1) 1) 1) 1) 1)
Siemens 8/34
Siemens 8/37 Siemens 8/38
Siemens Siemens

8 9 10 11 12 13

LSP2092-afp.eps

LSP2093-afp.eps

Fig. 8/37 Short-circuit link for current contacts

Fig. 8/38 Short-circuit link for voltage contacts/ indications contacts

1) Your local Siemens representative can inform you on local suppliers.

14 15

Siemens SIP · Edition No. 8 8/33

Transformer Differential Protection / 7UT6
Connection diagram
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Fig. 8/39 Connection diagram
8/34 Siemens SIP · Edition No. 8

Transformer Differential Protection / 7UT6
Connection diagram

Fig. 8/40a Additional setting by jumpers: Separation of common circuit of fast BO1 to BO5 with jumpers X80, X81, X82. Switching of fast BO7, BO8 as NO contact or NC contact with jumpers X41, X42, X43.
1) Configuration of binary outputs up to hardware-version .../CC For advanced flexibility see Fig. 8/40a. Fig. 8/40 Connection diagram 7UT613

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 8/35

Transformer Differential Protection / 7UT6
Connection diagram

Fig. 8/41a

Additional setting by jumpers:

Separation of common circuit of

fast BO1 to BO5 with jumpers X80,

X81, X82. Switching of fast BO7, BO8 as NO contact or NC contact

with jumpers X41, X42, X43

14 15

1) Configuration of binary outputs up to hardware-version .../CC For advanced flexibility see Fig. 8/41a.
2) High-speed contacts (option), NO only 3) High-speed contacts (option)
Fig. 8/41 Connection diagram 7UT63

8/36 Siemens SIP · Edition No. 8

Transformer Differential Protection / 7UT6
Connection diagram

1) High-speed contacts (option), NO only 2) High-speed contacts (option)
Fig. 8/42 Connection diagram 7UT635 part 1; continued on following page

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 8/37

Transformer Differential Protection / 7UT6
Connection diagram

Fig. 8/43 Connection diagram 7UT635 part 2

8/38 Siemens SIP · Edition No. 8

Busbar Differential Protection

Page

SIPROTEC 7SS52 distributed numerical busbar

and breaker failure protection

9/3

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
9/2 Siemens SIP · Edition No. 8

Busbar Differential Protection / 7SS52
SIPROTEC 7SS52 distributed numerical busbar and breaker failure protection

Function overview

Busbar protection functions ·Busbar differential protection ·Selective zone tripping ·Very short tripping time (<15 ms) ·Extreme stability against external fault,
short saturation-free time ( 2 ms) ·Phase-segregated measuring systems ·Integrated check zone ·48 bays can be configured ·12 busbar sections can be protected ·Bay-selective intertripping

LSP2392-afpen.tif

Fig. 9/1 SIPROTEC 7SS52 busbar protection system
Description
The SIPROTEC 7SS52 numerical protection is a selective, reliable and fast protection for busbar faults and breaker failure in medium, high and extra-high voltage substations with various possible busbar configurations.
The protection is suitable for all switchgear types with iron-core or linearized current transformers. The short tripping time is especially advantageous for applications with high fault levels or where fast fault clearance is required for power system stability.
The modular hardware allows the protection to be optimally matched to the busbar configuration. The decentralized arrangement allows the cabling costs in the substation to be drastically reduced. The 7SS52 busbar protection caters for single, double or triple busbar systems with or without and quadruple busbar systems without transfer bus with up to: 48 bays,
16 bus couplers, and 24 sectionalizing disconnectors and 12 busbar sections.

Breaker failure protection functions ·Breaker failure protection (single-phase
with/without current) ·5 operation modes, selectable per bay ·Separate parameterization possible for
busbar and line faults ·Independently settable delay times for
all operation modes ·2-stage operation bay trip repeat/trip busbar ·Intertrip facility (via teleprotection interface) ·"Low-current" mode using the circuit-breaker auxiliary contacts
Additional protection functions ·End-fault protection with intertrip or bus zone trip ·Backup overcurrent protection per bay unit (definite-time or
inverse-time) ·Independent breaker failure protection per bay unit
Features ·Distributed or centralized installation ·Easy expansion capability ·Integrated commissioning aids ·Centralized user-friendly configuration / parameterization
with DIGSI ·Universal hardware
Communication interfaces ·FO interface
IEC 60870-5-103 protocol ·Electrical interface
IEC 61850 protocol with EN 100 module (firmware V4.6)

1 2 3 4 5 6 7 8 9 10 11 12

15
Siemens SIP · Edition No. 8 9/3

LSA2180-bgpen.eps

Busbar Differential Protection / 7SS52
Application

Application

The 7SS52 distributed numerical busbar

and breaker failure protection system is

a selective, reliable and fast protection

for busbar faults and breaker failure in medium, high and extra-high voltage

substations with various possible busbar

configurations. The protection is suitable

for all switchgear types with iron-core or

linearized current transformers. The short

tripping time is especially advantageous

for applications with high fault levels or

where fast fault clearance is required for

power system stability.

The modular hardware design allows

the protection system to be optimally

matched to the busbar configuration.

The distributed arrangement allows the

cabling costs between bay and substation

to be drastically reduced. The 7SS52 bus-

bar protection caters for single, double,

triple and quadruple busbar systems with

or without transfer bus with up to:

48 bays

16 bus couplers 24 sectionalizing disconnectors

12 busbar sections

8 Fig. 9/2 Distributed system structure

1) Feeder currents, disconnector status trip commands 2) Disconnector status

14 15
9/4 Siemens SIP · Edition No. 8

Fig. 9/3 Protection functions of the central unit and the bay units

Busbar Differential Protection / 7SS52
Construction

Construction

The distributed bay units measure the 3 phase currents in each bay. The rated input current is 1 or 5 A and therefore eliminates the need for interposing current transformers. The disconnector status, breaker failure protection triggering, bay out-of- service and other bay status information is derived via marshallable binary inputs in the bay units. The complete information exchange is conveyed to the central unit via a fiberoptic interface. The bay unit also has an interface on the front side for connection to a PC for operation and diagnosis. The trip and intertrip commands are issued via trip contacts in the bay units. The 7XP20 standard housing is available in a flush or surface mounting version (7SS523).
The central unit is connected to the bay units via fiber-optic communication links. The connection is built up in a star configuration. The central unit also contains serial ports for system configuration via PC or communication with a substation control system, an integrated LC Display with keypad and marshallable binary inputs, LEDs and alarm relays. The central unit is available in a 19" SIPAC module rack version for either cubicle or wall mounting.
Because of its modular hardware design, it is easy to adapt the central unit to the substation or to expand it with further modules each being connected with up to 8 bay units.
Each bay unit and the central unit has its own internal power supply.

Fig. 9/4 7SS522 central unit front view of SIPAC subrack version Fig. 9/5 7SS522 central unit rear view

LSP2803.tif

LSP2377-afpen.tif

1 2 3 4 5 6 7 8 9 10

LSP2076-afp.tif LSP2516.tif

Fig. 9/6 7SS523 bay unit front view of panel / flush / cubicle mounting unit

Fig. 9/7 7SS525 bay unit front view of panel/flush/cubicle mounting unit

15
Siemens SIP · Edition No. 8 9/5

Busbar Differential Protection / 7SS52
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Protection functions

Busbar protection
The main function of the 7SS52 is busbar protection, and has the following characteristics:
·Evaluation of differential currents, with stabilization by through-currents based on the proven performance of the Siemens busbar protection 7SS1 and 7SS50/51, currently in service worldwide
·Selective busbar protection for busbars with up to 12 busbar sections and 48 bays
·Integrated "check zone" (evaluation of all busbar section currents without use of the disconnector replica)
·Very short tripping time (15 ms typical)
·Selective detection of short-circuits, also for faults on the transfer bus, with transfer trip to the remote end.
·Detection and clearance of faults between the current transformer and the circuit-breaker via current measurement and selective unbalancing.
·Tripping only when all three fault detection modules recognize a busbar fault (2 measurement processors and check zone processor)
·No special CT requirements (stability is guaranteed, even when the CTs saturate after 2 ms)
·Selective output tripping relays per feeder in bay units.

The pickup characteristic can be set independently for selective busbar protection, for the "check zone" and for the breaker failure protection.
Fig. 9/8 Standard characteristic

Mode of operation
The 7SS52 protection relay offers complete numerical measuredvalue processing from sampling to digital conversion of the measured variables through to the circuit-breaker tripping decision. The bay units dispose of sufficient powerful contacts to directly trip the circuit-breaker.
For each busbar section and for all three phases, two independent processors execute the protection algorithm on alternate data samples. Based on the proven performance of the 7SS1 and 7SS50/51, this method of measurement ensures highest stability even in case of high short-circuit currents and CT saturation.
In addition, an disconnector status independent check-zone measurement is executed on a further processor thus increasing the protection against unwanted operation. All three processors must reach a trip decision independently before the trip command is released.
The disconnector status is monitored using normally open and normally closed contacts to enable plausibility checks for both status and transition time. The contact monitoring voltage is also supervised.
In case of an auxiliary voltage failure in the bay, the latest disconnector status is stored and a bay-selective indication of the failure is issued.
The assignment of the feeder currents to the corresponding busbar systems is controlled by software via the disconnector replica. The disconnector replica is applied for both busbar protection and breaker failure protection.
The integrated breaker failure protection function provides phase-segregated two-stage operation (bay-specific trip repeat, trip bus section). Alternatively, an external breaker failure protection relay can issue its trip commands via the disconnector replica in the 7SS52.

Fig. 9/9 Ground-fault characteristic
Breaker failure protection
The 7SS52 protection includes an integrated breaker failure protection with the following features: ·Five breaker failure protection modes that are selectable:
1. Following the issue of a trip signal from a feeder protection, the busbar protection monitors the drop-off of the trip signal. If the feeder current is not interrupted before a set time delay the polarity of the feeder current is reversed, which results in a differential current in the corresponding section of the bus protection. For this function, a separate parameter set is used.
2. Following a trip signal from a feeder protection, a trip signal will be output after a settable time delay from the 7SS52 protection to the corresponding feeder circuit-breaker. If this second trip signal is also unsuccessful, the unbalancing procedure according to mode 1) as described above will take place.
3. With external stand-alone breaker failure protection, the disconnector replica of the 7SS52 may be used to selectively trip the busbar section with the faulty circuit-breaker.
4. Following a trip signal from the feeder protection, the 7SS52 monitors the drop-off of the trip signal. If, after a settable time, the current does not fall below a settable limiting value, busbar-selective feeder trip commands are issued with the help of the disconnector replica within the 7SS52.
5. Following a trip signal from a feeder protection, a trip signal will be output after a settable time delay from the 7SS52 protection to the corresponding feeder circuit-breaker. If this second trip signal is also unsuccessful, the tripping as described under 4) will take place.

9/6 Siemens SIP · Edition No. 8

Busbar Differential Protection / 7SS52
Protection functions

·For single-pole or multi-pole starting, delay times are available.
·Breaker failure detection following a busbar fault by comparison of the measured current with a set value.
·For all modes of breaker failure protection, a transfer trip command output contact is provided for each feeder to initiate remote tripping.

Sensitive tripping characteristic
In some applications, e.g. within resistive grounded networks, single-phase shortcircuit currents are limited to rated current values. In order to provide a busbar protection for these cases, an independent characteristic is available. This characteristic presents separate parameters for the pickup threshold, as well as for a limitation of efficiency. The activation of the characteristic takes place by means of a binary input in the central unit, e.g. by recognizing a displacement voltage.

LSP2516.tif

End-fault protection
The location of the current transformer normally limits the measuring range of the busbar protection. When the circuitbreaker is open, the area located between the current transformer and the circuitbreaker can be optimally protected by means of the end-fault protection. In the event of a fault, depending on the mounting position of the current transformer, instantaneous and selective tripping of the busbar section or intertripping of the circuit-breaker at the opposite end occurs.

Fig. 9/10 Fault record

LSP2516.tif

Backup protection
As an option, a two-stage backup protection, independent of the busbar protection is included in every bay unit. This backup protection is completed by means of a breaker failure protection. The parametrization and operation can be carried out in the central unit or locally in each bay unit with the DIGSI operating program.

Fig. 9/11 DIGSI plant monitoring

Disconnector replica
The disconnector replica is used for both the busbar protection and the breaker failure protection.
The following features characterize the disconnector replica function: ·Includes up to 48 bays and 12 busbar sections ·Integrated bi-stable disconnector status characteristic (status
stored on loss of auxiliary power). ·Disconnector transition time monitoring.

·By the assignment "NOT open = closed", the disconnector is taken to be CLOSED during the transition time. Accurate matching of the disconnector auxiliary contacts with the main contact is not required.
·Menu-guided graphic configuration with DIGSI operating program.
·LEDs in the bay modules indicate the actual status of the busbar disconnector.
·Dynamic visualization of the substation with DIGSI on the central unit.

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 9/7

Busbar Differential Protection / 7SS52
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Tripping command / reset
The tripping output processing for the 7SS52 protection has the following features: ·Bay-selective tripping by bay units ·Settings provided for overcurrent release of the tripping com-
mand (to enable selective tripping of infeeding circuits only) ·Settable minimum time for the trip command. ·Current-dependent reset of the tripping command.
Disturbance recording
The digitized measured values from the phase currents and the differential and stabilizing currents of the busbar sections and check zone are stored following a trip decision by the 7SS52 or following an external initiation via a binary input. Pre-trigger and post-fault times with regard of the trip command can be set. Up to 8 fault recordings are stored in the 7SS52. The fault records may be input to a PC connected to the central unit, using the menu-guided DIGSI operating program. Then, the SIGRA graphics program makes it possible to easily analyze the fault recordings.
Marshallable tripping relays, binary inputs, alarm relays and LEDs
The bay units are equipped with marshallable command relays for direct circuit-breaker tripping. For each bay there are 9 (7SS523) or 8 (7SS525) duty contacts available.
For user-specific output and indication of events, 16 alarm relays and 32 LEDs in the central unit are freely marshallable.
Several individual alarms may be grouped together.
The central unit has marshallable binary inputs with: ·Reset of LED display ·Time synchronization ·Blocking of protection functions
The bay units have marshallable binary inputs: ·Disconnector status closed/open ·Phase-segregated start of circuit-breaker failure protection ·Release of circuit-breaker failure protection ·Release of TRIP command ·Circuit-breaker auxiliary contacts ·Bay out of service ·Test of circuit-breaker tripping
Measurement and monitoring functions
In the 7SS52 protection relay, a variety of measurement and monitoring functions is provided for commissioning and maintenance. These functions include: ·Measurement and display of the phase currents of the feeders
in the central unit and bay units. ·Measurement and display (on the integrated LCD or PC) of the
differential and stabilizing currents of all measuring systems in the central unit and the bay units. ·Monitoring of busbar-selective and phase-segregated differential currents with busbar-selective blocking / alarming ·Monitoring of the differential currents of the check zone with alarming / blocking

·Phase-segregated trip test including control of feeder circuitbreaker (by central or bay unit)
·Removal of a bay from the busbar measurement processing during feeder service and maintenance via central or bay units (bay out of service)
·Blocking of breaker failure protection or tripping command for testing purposes.
·Disconnector replica freezing (maintenance) with alarm indication ("Disconnector switching prohibition").
·Cyclic tests of measured-value acquisition and processing and trip circuit tests including coils of the command relays.
Event recording
The 7SS52 protection provides complete data for analysis of protection performance following a trip or any other abnormal condition and for monitoring the state of the relay during normal service.
Up to 200 operational events and 80 fault annunciations with a resolution of one millisecond may be stored in two independent buffers:
·Operational indications This group includes plant/substation operation events, for example disconnector switching, disconnector status discrepancies (transition time limit exceeded, loss of auxiliary voltage, etc.) or event/alarm indications
·Tripping following a busbar short-circuit fault or circuit-breaker failure.
Settings
A PC can be connected to the operator interface located at the front panel or the rear of the central unit. An operating program is available for convenient and clear setting, fault recording and evaluation as well as for commissioning. All settings of the busbar or breaker failure protection, as well as settings of additional functions such as backup protection, need only be parameterized at the central unit. Settings at the bay units are not necessary. With the help of the integrated keypad and display on the central unit, all setting parameters may be read out. Keypad, display (7SS523) and the front side interface of the bay units serve for commissioning, display of operational values and diagnosis. All parameters are written into nonvolatile memories to ensure that they are retained even during loss of auxiliary voltage.
Configuration, visualization
The configuration of the 7SS52 is effected by means of a graphics-orientated editor included in the DIGSI operation program. For frequently used bay types, a symbol library is available. Enhancements can be easily effected anytime.
A graphical configuration visualizes the states of the disconnector position, the circuit-breaker and measuring values.
Self-monitoring
Hardware and software are continuously monitored and any irregularity is immediately detected and alarmed. The selfmonitoring feature improves both the reliability and the availability of the 7SS52. The following quantities are monitored:
·The current transformer circuits
·The analog-to-digital conversion

9/8 Siemens SIP · Edition No. 8

Busbar Differential Protection / 7SS52
Protection functions, communication

·All internal supply voltages ·The program memory ·The program running times by a watch dog function ·The disconnector status ·The three channel tripping circuit
Maximum lifetime and reliability
The hardware of the 7SS52 units is guaranteed by more than 20 years of experience in numerical protection design at Siemens. The number of components employed is reduced through use of a powerful microprocessor in conjunction with highly-integrated components, thus enhancing the reliability. The experience gained by Siemens in production of over 1 million numerical protection units has been incorporated in the software design. The most modern manufacturing methods together with effective quality control ensure high reliability and a long service life.
Battery monitoring
The internal battery is used to back-up the clock and memory for storage of switching statistics, status and fault indications and fault recording, in the event of a power supply failure. The processor checks its capacity at regular intervals. If the capacity of the battery is found to be declining, an alarm is generated. Routine replacement is therefore not necessary. All setting parameters are stored in the Flash-EPROM, and therefore not lost if the power supply or the battery fails.
Functions for testing and commissioning
The 7SS52 offers auxiliary functions for commissioning. The physical status of all binary inputs and output relays of the central unit can be displayed and directly altered to facilitate testing.
All measured values can be clearly depicted by means of DIGSI and simultaneously displayed in different windows as primary or percentage values.
The 7SS52 units are provided with a circuit-breaker test function. Single-pole and three-pole TRIP commands can be issued.
Data transmission lockout
Data transmission lockout can be activated, so as to prevent transfer of information to the control center during work on a circuit bay.
Test mode
During commissioning, a test mode can be selected; all indications then have a test mode suffix for transmission to the control system.

Communication
Serial communication
With respect to communication, particular emphasis is placed on the customer requirements in energy automation: ·Every data item is time-stamped at the source, i.e. where it
originates. ·Already during the process of communication, information
is assigned to the cause thereof (e.g. assignment of the indication "circuit-breaker TRIP" to the corresponding command). ·The communication system automatically handles the transfer of large data blocks (e.g. fault recordings or parameter data files). The user has access to these features without any additional programming effort.
Local and remote communication
The 7SS52 central unit provides several serial communication interfaces for various tasks: ·Front interface for connecting a PC ·Rear-side service interface (always provided) for connection to
a PC, either directly or via a modern ·System interface for connecting to a control system via
IEC 60870-5-103 protocol. ·System interface (EN 100 module) for connecting to a control
system via IEC 61850 protocol ·Time synchronization via IRIG-B / DCF / system interface
Serial front interface (central unit and bay units)
There is a serial RS232 interface on the front of all the units. All of the unit's functions can be set on a PC by means of the DIGSI 4 protection operation program. Commissioning tools and fault analysis are also built into the program and are available through this interface.
Rear-mounted interfaces (central unit only)
A number of communication modules suitable for various applications can be fitted in the rear of the flush-mounting housing. The interface modules support the following applications: ·Service interface
The service interface was conceived for remote access to a number of protection units via DIGSI. It can be an electrical RS232/RS85 or an optical interface. ·RS485 bus With this data transmission via copper conductors, electromagnetic fault influences are largely eliminated by the use of twisted-pair conductors. Upon failure of a unit, the remaining system continues to operate without any problem.
System interface
Communication with a central control system takes place through this interface. Radial or ring type station bus topologies can be configured depending on the chosen interface. Furthermore, the units can exchange data through this interface via Ethernet and IEC 61850 protocol and can also be operated by DIGSI.

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Siemens SIP · Edition No. 8 9/9

Busbar Differential Protection / 7SS52
Communication

IEC 61850 protocol (retrofittable)

The Ethernet-based IEC 61850 protocol is the worldwide standard for protection

and control systems used by power supply

corporations. By means of this protocol,

information can also be exchanged directly between protection units so as

to set up simple masterless systems for

bay and system interlocking. Access to

the units via the Ethernet bus will also be

possible with DIGSI.

IEC 60870-5-103 protocol

The IEC 60870-5-103 protocol is an inter-

national standard for the transmission of

protective data and fault recordings. All

messages from the unit and also control

commands can be transferred by means

of published, Siemens-specific extensions to the protocol.

Time synchronization

The battery-backed clock of the 7SS52 central unit can be synchronized via:

Fig. 9/12 Communication structure with DIGSI and IEC 60870-5-103

·DCF 77 signal via time synchronization

receiver

·IRIG-B satellite signal via time synchroni-

zation receiver

·Minute-pulse via binary input

·System interface by the substation control, e.g. SICAM

Date and time with milliseconds resolu-

tion is assigned to every indication. The

synchronization of the 7SS52 bay units is automatically effected with the central

unit.

11 12

Fig. 9/13 Communication structure for station bus with Ethernet and IEC 61850, FO ring

15
9/10 Siemens SIP · Edition No. 8

Busbar Differential Protection / 7SS52
Technical data

General unit data

Input circuits

Rated current IN

Rated frequency fN

Thermal overload Continuous

capability in current 10 s

path

1 s

Dynamic overload capability

Burden of current inputs

At IN = 1 A At IN = 5 A

Auxiliary voltage

Rated auxiliary voltage Vaux

Central unit

Rated auxiliary voltage Vaux

Bay unit

Permissible tolerance Vaux

Maximum ripple

Power consumption

Central unit

Quiescent Energized

Bay unit

Quiescent Energized

Max. bridging time during loss of voltage supply

Binary inputs

Number of binary inputs

Bay unit Central unit

Voltage range

Current consumption

Alarm/event contacts

Central unit

Number of relays

Marshallable Fixed

Switching capacity Make/Break

Switching voltage

Permissible current

Bay unit
Number of relays

Marshallable Fixed

Switching capacity Make/Break

Switching voltage AC/DC 250 V

Permissible current 1 A

Command contacts

Number of relays (bay unit)

Switching capacity
Switching voltage Permissible current

Make Break
Continuous 0.5 s

1 or 5 A 50/60 Hz 4 x IN 10 x IN 100 x IN 250 x IN
< 0.1 VA < 0.2 VA

DC 48 V to 250 V

20 to +20 %

15 %

Configuration dependent

35 to 55 W < 70 W

7SS523

7SS525

12 W 16 W

10 W 14 W

> 50 ms at Vaux 60 V

7SS523

7SS525

DC 24 to 250 V

Approx. 1.5 mA/input

16 (each 1 NO contact) 1 (2 NC contacts)

20 W/VA

AC/DC 250 V

1 A

7SS523

7SS525

1 (1 NO contact) 1 (1 NO contact) 1 (2 NC contacts) 1 (1 NC contacts)

20 W/VA

AC/DC 250 V

1 A

7SS523

7SS525

4 (each 2 NO 3 (each 2 NO

contacts)

1 (1 NO contact) 2 (1 NO contact)

1000 W/VA 30 W/VA

AC/DC 250 V

5 A 30 A

LEDs

Central unit

Operation

Green

indication

Device failure

Red

Marshallable

Red

Bay unit Operation indication Device failure Indications

Green
Red Green Red

1
1 5 (7SS523)/ (7SS525) 11 (7SS523)/1 (7SS525)

Control, displays

Central unit LC Display Membrane keyboard

4 lines x 20 characters 24 keys

Bay unit (7SS523) LC Display Membrane keyboard

4 lines x 16 characters 12 keys

Unit design (degree of protection according to EN 60529)

Central unit Cubicle Housing for wall mounting SIPAC subrack

IP 54 IP 55 IP 20

Bay unit

7SS523

7SS525

Housing Terminals

IP 51 IP 21

IP 20

Weight at max. configuration Central unit
SIPAC subrack Surface-mounting housing

14.3 kg 43.0 kg

Bay unit

7SS523

7SS525

Flush mounting Surface mounting

8.1 kg 11.8 kg

5.5 kg

1 2 3 4 5 6 7 8 9 10 11 12 13 14

15
Siemens SIP · Edition No. 8 9/11

Busbar Differential Protection / 7SS52
Technical data

1 2 3 4 5 6 7 8 9 10 11 12 13

Electrical tests

Specification

Standards

IEC 60255-5, DIN 57435 part 303

High-voltage test (routine test), 2 kV (r.m.s.), 50 Hz except DC voltage supply input

High-voltage test (routine test), only DC voltage supply input

DC 2.8 kV

Impulse voltage test (type test), all circuits, class III

5 kV (peak), 1.2/50 µs, 0.5 J, 3 positive and 3 negative impulses at intervals of 5 s

EMC tests for interference immunity; type test

Standards

IEC 60255-6, IEC 60255-22 (international product standard), EN 50082-2 (European generic standard for industrial environment), VDE 0435 part 303 (German product standard)

High-frequency test with 1 MHz interference IEC 60255-2-1, class III and VDE 0435 part 303, class III

2.5 kV (peak), 1 MHz, = 15 µs, 400 surges/s, duration 2 s

Electrostatic discharge IEC 60255-22-2, class IV and IEC 61000-4-2, class IV
Irradiation with radio-frequency field, non-modulated IEC 60255-22-3, class III

8 kV contact discharge, 15 kV air discharge, both polarities, 150 pF, Ri = 330
10 V/m, 27 to 500 MHz

Irradiation with radio-frequency field, amplitude-modulated IEC 61000-4-3, class III

10 V/m, 80 to 1000 MHz, AM 80 %, 1 kHz

Irradiation with radio-frequency field, pulse-modulated ENV 50204, class III

10 V/m, 900 MHz, repetition rate 200 Hz, duty cycle 50 %

Fast transients interference/bursts IEC 60255-22-4, class IV; IEC 61000-4-4, class IV; IEC 60801-4
Line-conducted disturbances induced by radio-frequency fields, amplitude-modulated IEC 61000-4-6, class III

4 kV, 5/50 ns, 5 kHz, burst length = 15 ms, repetition rate 300 ms, both polarities, Ri = 50 , duration 1 min
10 V, 150 kHz to 80 MHz, AM 80 %, 1 kHz

Power frequency magnetic field IEC 61000-4-8, class IV; IEC 60255-6

30 A/m continuous, 300 A/m for 3 s, 50 Hz 0.5 mT; 50 Hz

EMC tests for interference emission; type test

Standard

EN 50081-2 (European generic standard for industrial environment)

Conducted interference voltage, auxiliary voltage CISPR 11, EN 55011 and VDE 0875 part 11

150 kHz to 30 MHz, limit class B

Radio interference field strength CISPR 11, EN 55011 and VDE 0875 part 11

30 to 1000 MHz, limit class B

Mechanical stress tests Specification Standards Permissible mechanical stress
During service
During transport

IEC 60255-21-1, IEC 6068-2
10 to 60 Hz, 0.035 mm amplitude 60 to 500 Hz, 0.5 g acceleration 5 to 8 Hz, 7.5 mm amplitude 8 to 500 Hz, 2 g acceleration

Climatic stress tests Temperatures Standard Permissible ambient temperature In service
For storage During transport During start-up
Humidity Standards It is recommended to arrange the units in such a way that they are not exposed to direct sunlight or pronounced temperature changes that could cause condensation.

IEC 60255-6
10 °C to +55 °C (bay unit) 5 °C to +55 °C (central unit) 25 °C to +70 °C 25 °C to +70 °C 10 °C to +55 °C (bay unit)
0 °C to +55 °C (central unit)
IEC 60068-2-3 Annual average 75 % relative humidity; on 56 days a year up to 93 % relative humidity; condensation not permissible!

15
9/12 Siemens SIP · Edition No. 8

Futher information can be found in the current manual at: www.siemens.com/siprotec

Busbar Differential Protection / 7SS52
Selection and ordering data

Description 7SS522 distributed busbar/breaker failure protection
Central unit Central unit 50/60 Hz
Rated auxiliary voltage DC 48 to 250 V
Unit design In subrack ES902C
Regional presettings/regional functions and languages Region DE, language German (language can be selected) Region World, language English (UK) (language can be selected) Region US, language English (US) (language can be selected) Region FR, language French (language can be selected) Region World, language Spanish (language can be selected) Region World, language Italian (language can be selected) Region World, language Russian (language can be selected)
System interface Without IEC 60870-5-103 protocol, optical 820 nm, ST connector IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector IEC 61850, 100 Mbit Ethernet, with integrated switch optical, double
Service interface (on rear of relay) DIGSI 4 / modem, electrical RS232 DIGSI 4 / modem, electrical RS485 DIGSI 4 / modem, optical 820 nm, ST connector
Additional functions without 1 with cross stabilisation
Equipped for 8 bays 16 bays 24 bays 32 bays 40 bays 48 bays
7SS523 distributed busbar / breaker failure protection Bay unit, frequency, housing, binary inputs and outputs Bay unit, 50/60 Hz, housing ½ x 19", 20 BI, 6 BO, 2 live status contacts
Rated current 1 A 5 A
Rated auxiliary voltage DC 48 to 250 V
Unit design 7XP2040-2 for flush mounting or cubicle mounting 7XP2040-1 for surface mounting 7XP2040-2 for flush mounting without glass cover
Additional functions Without additional functions With overcurrent-time protection

Order No. 7SS52 0 -
2 6

Order code

- A0-

A B C D E F G
0 3 9 9
1 2 3

L 0 R L 0 S

1 2

A B C D E F 7SS52 - A 0 1 - A A 1
3

1 5

5
C D E

0 1

3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 9/13

Busbar Differential Protection / 7SS52
Selection and ordering data

Description

7SS523 distributed busbar/breaker failure protection Bay unit, frequency 50/60 Hz;

Housing 1/3 x 19"; 10 BI, 6 BO, 1 live status contact

Rated current

1 A 5 A

Rated auxiliary voltage at converter

DC 48 to 250 V

Unit design

7XP2040-2 for panel flush mounting or cubicle mounting without glass cover

Additional functions

Without additional functions

With overcurrent-time protection

Order No. 7SS525 -

A 01- AA1

1 5
5
F
0 1

5
Accessories
6
7

Description
Connection cable Cable between PC/notebook (9-pin connector) and protection relay (9-pin connector) (contained in DIGSI 4, but can be ordered additionally)
Manual 7SS52 V4.7/V3.3 English

Order No.
7XV5100-4 C53000-G1176-C182-5

15
9/14 Siemens SIP · Edition No. 8

Busbar Differential Protection / 7SS52
Selection and ordering data

Fig. 9/14 Connection diagram 7SS522

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 9/15

Busbar Differential Protection / 7SS52
Connection diagram

Fig. 9/15 Connection diagram 7SS523

9/16 Siemens SIP · Edition No. 8

Live contact

LSA2949-bgpen.eps

Busbar Differential Protection / 7SS52
Connection diagram

Live contact
Fig. 9/16 Connection diagram 7SS525

LSA4164-ben.eps

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 9/17

Busbar Differential Protection / 7SS52
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
9/18 Siemens SIP · Edition No. 8

Relays for Various

Protection Applications

Page

SIPROTEC 7VK61 breaker management relay

10/3

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
10/2 Siemens SIP · Edition No. 8

Relays for Various Protection Applications / 7VK61
SIPROTEC 7VK61 breaker management relay

25 50BF 79 59 27 86 74TC
Fig. 10/1 SIPROTEC 7VK61 breaker management relay
Description
The SIPROTEC 4 breaker management relay 7VK61 is a highly flexible auto-reclosure, synchro-check and circuit-breaker failure protection unit. This unit is used for the single and three-pole auto-reclosure of a circuit-breaker, after this circuit-breaker has tripped due to a fault. The synchro-check function ensures that the two circuits being reconnected by closing the circuit-breaker are within a defined safe operating state before the CLOSE command is issued. The 7VK61 is also applicable as circuit-breaker failure protection. A breaker failure occurs when the circuit-breaker fails to correctly open and clear the fault after single or three-pole trip commands have been issued by the protection. It is then necessary to trip the relevant busbar zone (section) to ensure fault clearance. Together with the above-mentioned protection functions, the following additional functions of the 7VK61 can be applied: end-fault protection, pole-discrepancy protection, overvoltage protection and undervoltage protection. As a member of the numerical SIPROTEC 4 relay family, it also provides control and monitoring functions and therefore supports the user with regard to a cost-effective power system management.

LSP2458-afp.tif

Function overview
Protection functions ·Single and/or three-pole auto-reclosure ·Synchro-check with live/dead line/bus measurement ·Closing under asynchronous conditions
(consideration of CB operating time) ·Circuit-breaker failure protection with two stages
(single and three-pole with/without current) ·End-fault protection ·Pole-discrepancy protection ·Overvoltage/undervoltage protection
Control function ·Commands for control of CB and isolators
Monitoring functions ·Operational measured values ·Self-supervision of the relay ·Event buffer and fault protocols ·Oscillographic fault recording ·Monitoring of CB auxiliary contacts ·Switching statistics
Features ·All functions can be used separately ·Initiation/start by phase-segregated or 3-pole trip commands ·Auto-reclosure for max. 8 reclose cycles ·Evolving/sequential trip recognition ·Auto-reclosure with ADT, DLC, RDT ·Synchro-check with V, , f measurement ·Breaker failure protection with highly secure 2-out-of-4 current
check detectors ·Breaker failure protection with short reset time and negligible
overshoot time
CommunicatIon interfaces ·Front interface for connecting a PC ·System interface for connecting to a control system via various
protocols IEC 61850 Ethernet IEC 60870-5-103 protocol PROFIBUS DP DNP 3 ·Rear-side service/modem interface ·Time synchronization via IRIG-B or DCF77 or system interface

1 2 3 4 5 6 7 8 9 10 11 12 13

15
Siemens SIP · Edition No. 8 10/3

Relays for Various Protection Applications / 7VK61
Application

1 2 3 4 5 6 7 8 9 10 11 12

Application

The 7VK61 provides highly flexible breaker management. It applies to singlebreaker, ring-bus, and 1½ breaker installations. The auto-reclosure, synchronismcheck, breaker failure protection and voltage protection functions can be used separately or combined. Therefore the current and voltage transformer connection can be selected according to the required application.

The auto-reclosure function closes the circuit-breaker after this circuit-breaker has tripped due to a fault. The checksynchronism function ensures that the two circuits being reconnected by closing the circuit-breaker are within a defined safe operating state before the CLOSE command is issued.

The numerical 7VK61 relay provides

rapid backup fault clearance in case the

circuit-breaker nearest to the fault fails to

respond to a TRIP command. It is suitable

for power systems of all voltage levels

Fig. 10/2 Application and function diagram

with single and/or three-pole circuit-

breaker operation. The initiation signal can be issued from any protection or supervision equipment. Information from the circuit-breaker auxiliary contact is only required for the breaker failure protection during faults which produce little or no fault current flow, for instance due to a trip from the power transformer Buchholz protection.

If the requirements for protection, control and interlocking change, it is possible in the majority of cases to implement such changes by means of parameterization using DIGSI 4 without having to change the hardware. The use of powerful microcontrollers and the application of digital measured-value conditioning and processing largely sup-

Cost-effective power system management The SIPROTEC 4 units are numerical relays which also provide

presses the influence of higher-frequency transients, harmonics and DC components.

control and monitoring functions and therefore support the

user with regard to a cost-effective power system management. ANSI

Protection functions

The security and reliability of the power supply is increased as a result of minimizing the use of hardware.
The local operation has been designed according to ergonomic criteria. Large, easy-to-read backlit displays are provided.

50BF 59/27 25

Breaker-failure protection Overvoltage/undervoltage protection Synchro-check

The SIPROTEC 4 units have a uniform design and a degree of

functionality which represents a benchmark-level of perfor-

mance in protection and control.

74TC

Auto-reclosure Trip circuit supervision

Lockout (CLOSE command interlocking)

15
10/4 Siemens SIP · Edition No. 8

Relays for Various Protection Applications / 7VK61
Construction

Construction

Connection technique and housing with many advantages
and ½-rack sizes are available as housing widths of the SIPROTEC 7VK61 relays, referred to a 19" modular frame system. This means that previous models can always be replaced. The height is a uniform 255 mm for flush-mounting housings and 266 mm for surface-mounting housings for all housing widths. All cables can be connected with or without ring lugs.
In the case of surface mounting on a panel, the connection terminals are located above and below the housing in the form of screw-type terminals. The communication interfaces are located in a sloped case at the top and bottom of the housing.

Fig. 10/3 Flush-mounting housing with screw-type terminals

LSP2174-afp.tif LSP2166-afp.tif

Fig. 10/4 Rear view of flush-mounting

housing with covered connection terminals andwirings

LSP2219-afp.eps LSP2237-afp.tif

Fig. 10/5 Surface-mounting housing with screw-type terminals, example 7SA63

Fig. 10/6 Communication interfaces in a sloped case in a surface-mounting housing

15
Siemens SIP · Edition No. 8 10/5

Relays for Various Protection Applications / 7VK61
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13

Protection functions

Auto-reclosure (ANSI 79)

The 7VK61 relay is equipped with an auto-reclose function (AR). Usually the auto-reclosure interacts with the feeder protection via binary inputs and outputs.

The function includes several operating modes:
·3-pole auto-reclosure for all types of faults; different dead times are available depending on the type of fault
·1-pole auto-reclosure for 1-phase faults, no reclosing for multi-phase faults
·1-pole auto-reclosure for 1-phase and 3-pole auto-reclosing for multi-phase faults
·Multiple-shot auto-reclosure
·Interaction with the internal or an external synchro-check
·Monitoring of the circuit-breaker auxiliary contacts.

Fig. 10/7 Auto-reclosure and synchro-check with voltage measurement across a power transformer
Synchro-check (ANSI 25)

In addition to the above-mentioned operating modes, several other operating principles can be employed by means of the integrated programmable logic (CFC).
The 7VK61 allows the line-side voltages to be evaluated. A number of voltage-dependent supplementary functions are thus available:
·ADT The adaptive dead time is employed only if auto-reclosure at the remote station was successful (reduction of stress on equipment).
·DLC By means of dead-line check, reclosure is effected only when the line is deenergized (prevention of asynchronous breaker closure in case that the synchronism check can not be used).
·RDT Reduced dead time is employed in conjunction with autoreclosure where no teleprotection method is employed: when faults within the zone extension of a distance feeder protection but external to the protected line, are switched off for rapid auto-reclosure (RAR), the RDT function decides on the basis of measurement of the return voltage from the remote station which has not tripped, that the fault has been cleared by the protection on the faulted downstream feeder and that reclosure with reduced dead time may take place.

Where two network sections are switched in by control command or following a 3-pole auto-reclosure, it must be ensured that both network sections are mutually synchronous. For this purpose, a synchronism-check function is provided. After verification of the network synchronism, the function releases the CLOSE command. Consideration of the duration of the CB operating time before issuing the CLOSE command (especially important under asynchronous conditions and when several circuit-breakers with different operating times are to be operated by one single relay).
In addition, reclosing can be enabled for different criteria, e.g., when the busbar or line are not carrying a voltage (dead line or dead bus).
Breaker failure protection (ANSI 50BF)
The 7VK61 relay incorporates a two-stage circuit-breaker failure protection to detect failures of tripping command execution, for example due to a defective circuit-breaker. The current detection logic is phase-segregated and can therefore also be used in single-pole tripping schemes.
If the fault current is not interrupted after a settable time delay has expired, a retrip command or the busbar trip command will be generated. The breaker failure protection will usually be initiated by external feeder protection relays via binary input signals. Trip signals from the internal auto-reclosure logic or from the voltage protection can start the breaker failure protection as well.

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10/6 Siemens SIP · Edition No. 8

Relays for Various Protection Applications / 7VK61
Protection functions

Overvoltage protection, undervoltage protection (ANSI 59, 27)
The 7VK61 contains a number of overvoltage measuring elements. Each measuring element is of two-stage design. The following measuring elements are available:
·Phase-to-ground overvoltage
·Phase-to-phase overvoltage
·Zero-sequence overvoltage The zero-sequence voltage can be connected to the 4th voltage input (not in conjunction with syncho-check) or be derived from the phase voltages.
·Negative-sequence overvoltage
Tripping by the overvoltage measuring elements can be effected either at the local circuit-breaker or at the remote station by means of a transmitted signal.
The 7VK61 is fitted, in addition, with three two-stage undervoltage measuring elements:
·Phase-to-ground undervoltage
·Phase-to-phase undervoltage
·Positive-sequence undervoltage
The undervoltage measuring elements can be blocked by means of a minimum current criterion and by means of binary inputs.
End-fault protection
When the circuit-breaker is open, the area located between the current transformer and the circuit-breaker can be optimally protected by means of the end-fault protection. In the event of a fault, an independently settable time delay is started after a valid initiation has been received and the circuit-breaker auxiliary contacts indicate an open circuit-breaker position, with current still flowing (see Fig. 10/8). Depending on the mounting position of the current transformer, instantaneous tripping of the busbar section or intertripping of the circuit-breaker at the opposite end occurs.
Pole-discrepancy protection
This function ensures that any one or two poles of a circuitbreaker do not remain open for longer than an independently settable time (i.e. unsymmetrical conditions). This time stage is initiated when current (above the set value) is flowing in any 1 or 2 phases, but not in all 3 phases. Additionally, the circuitbreaker auxiliary contacts (if connected) are interrogated and must show the same condition as the current measurement. Should this time delay expire, then a three-pole trip command is issued. This function is normally used when single-pole autoreclosing is applied.

Fig. 10/8 End-fault between circuit-breaker and current transformer
Trip circuit supervision (ANSI 74TC)
One or two binary inputs for each circuit-breaker pole can be used for monitoring the circuit-breaker trip coils including the connecting cables. An alarm signal is issued whenever the circuit is interrupted. The trip circuit supervision function requires one or two independent potential-free binary inputs per trip circuit. To make existing (non potential-free) binary inputs potentialfree, external optocoupler modules can be applied.
Lockout (ANSI 86)
Under certain operating conditions, it is advisable to block CLOSE commands after a final TRIP command of the relay has been issued. Only a manual `Reset' command unblocks the CLOSE command. The 7VK61 is equipped with such an interlocking logic.
Monitoring functions
The 7VK61 relay provides comprehensive monitoring functions covering both hardware and software. Furthermore, the measured values are continuously checked for plausibility. Therefore the current and voltage transformers are also included in this monitoring system.
If all voltages are connected, the relay will detect secondary voltage interruptions by means of the integrated fuse failure monitor. Immediate alarm and blocking of the synchronism check and dead line check is provided for all types of secondary voltage failures. Additional measurement supervision functions are ·Symmetry of voltages and currents (in case of appropriate
transformer connection) ·Broken-conductor supervision (if current transformers are
connected) ·Summation of currents and voltages (in case of appropriate
transformer connection) ·Phase-sequence supervision (if three voltage transformers are
connected)

1 2 3 4 5 6 7 8 9 10 11 12 13

15
Siemens SIP · Edition No. 8 10/7

Relays for Various Protection Applications / 7VK61
Communication

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Communication

With respect to communication, particular emphasis is placed on the customer requirements in energy automation:
·Every data item is time-stamped at the source, i.e. where it originates.
·Already during the process of communication, information is assigned to the cause thereof (e.g. assignment of the indication "circuit-breaker TRIP" to the corresponding command).
·The communication system automatically handles the transfer of large data blocks (e.g. fault recordings or parameter data files). The user has access to these features without any additional programming effort.
·For the safe execution of a control command the corresponding data telegram is initially acknowledged by the unit which will execute the command. After the release and execution of the command a feedback signal is generated. At every stage of the control command execution particular conditions are checked. If these are not satisfied, command execution may be terminated in a controlled manner.
The units offer a high degree of flexibility by supporting different standards for connection to industrial and power automation systems. By means of the communication modules, on which the protocols run, exchange and retrofit is possible. Therefore, the units will also in future allow for optimal adaptation to changing communication infrastructure such as the application of Ethernet networks (which will also be used increasingly in the power supply sector in the years to come).

Fig. 10/9 IEC 60870-5-103 star-type RS232 copper conductor connection or fiber-optic connection

Service/modem interface
7VK61 units are always fitted with a rear-side hardwired service interface, optionally as RS232 or RS485. In addition to the front-side operator interface, a PC can be connected here either directly or via a modem.
Time synchronization interface
The time synchronization interface is a standard feature in all units. The supported formats are IRIG-B and DCF77.
Reliable bus architecture ·RS485 bus
With this data transmission via copper conductors, electromagnetic fault influences are largely eliminated by the use of twisted-pair conductors. Upon failure of a unit, the remaining system continues to operate without any problem.
·Fiber-optic double ring circuit The fiber-optic double ring circuit is immune to electromagnetic interference. Upon failure of a section between two units, the communication system continues to operate without disturbance. It is usually impossible to communicate with a unit that has failed. Should a unit fail, there is no effect on the communication with the rest of the system.

Fig. 10/10 Bus structure for station bus with Ethernet and IEC 61850 with fiber-optic ring
Retrofitting: Modules for every type of communication
Communication modules for retrofitting are available for the entire SIPROTEC 4 unit range. These ensure that, where different communication protocols (IEC 61850, IEC 60870-5-103, PROFIBUS, DNP, etc.) are required, such demands can be met. For fiber-optic communication, no external converter is required for SIPROTEC 4.
IEC 61850 protocol
The Ethernet-based IEC 61850 protocol is the worldwide standard for protection and control systems used by power supply corporations. Siemens was the first manufacturer to support this Standard. By means of this protocol, information can also be exchanged directly between bay units so as to set up simple masterless systems for bay and system interlocking. Access to the units via the Ethernet bus is also be possible with DIGSI.
IEC 60870-5-103 protocol
IEC 60870-5-103 is an internationally standardized protocol for efficient communication with protection relays. IEC 60870-5-103 is supported by a number of protection device manufacturers and is used worldwide. Supplements for the control function are defined in the manufacturer-specific part of this standard.

10/8 Siemens SIP · Edition No. 8

Relays for Various Protection Applications / 7VK61
Communication

PROFIBUS DP
PROFIBUS DP is an industrial communications standard and is supported by a number of PLC and protection device manufacturers.

DNP 3.0

DNP 3.0 (Distributed Network Protocol, Version 3) is an internationally recognized protection and bay unit communication protocol. SIPROTEC 4 units are Level 1 and Level 2 compatible.

System solutions for protection and station control

Fig. 10/11 820 nm fiber-optic communication Fig. 10/12 RS232/RS485 electrical

module

communication module

LSP3.01-0021.tif

Together with the SICAM power automation system, SIPROTEC 4 can be used with PROFIBUS DP. Over the low-cost electrical RS485 bus, or interference-free via the optical double ring, the units exchange information with the control system. Units equipped with IEC 60870-5-103 interfaces can be connected to SICAM in parallel via the RS485 bus or connected in star by fiber- optic link. Through this interface, the system is open for the connection of units of other manufacturers (see Fig. 10/14).

Fig. 10/13 Fiber-optic Ethernet communication module for IEC 61850 with integrated Ethernet switch

For IEC 61850, an interoperable system solution is offered with SICAM PAS. Via the 100 Mbits/s Ethernet bus, the units are linked with PAS electrically or optically to the station PC. The interface is standardized, thus also enabling direct connection of units of other manufacturers to the Ethernet bus.

With IEC 61850, however, the units can also be used in other manufacturers' systems. Units with an IEC 60870-5-103 interface are connected with PAS via the Ethernet station bus by means of serial/ Ethernet converters. DIGSI can also be used via the same station bus.

Fig. 10/14 Communication

LSP2162-afpen.tif LSP2163-afpen.tif

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 10/9

Relays for Various Protection Applications / 7VK61
Typical connection

Typical connection

Connection for current and voltage

transformers

With the transformer connection as shown

in Fig. 10/15, it is possible to use the complete scope of functions of 7VK61, i.e.

breaker failure protection, synchronism-

check with 3-phase dead line check (with

or without auto-reclosure), complete measured value monitoring, voltage protection,

and the complete range of operational

measured values.

5
Fig. 10/15 Complete connection of all current and voltage transformers
6

Alternative: Connection for current

transformers only

The connection for current transformers

only provides breaker failure protection and

current operational measured values.
8

Fig. 10/16 Typical current transformer connection for breaker failure protection

15
10/10 Siemens SIP · Edition No. 8

Relays for Various Protection Applications / 7VK61
Typical connection

Alternative: Connection for two voltage

transformers In case of a connection for two voltage

transformers, synchro-check and two

operational measured voltages, and addi-

tionally synchro-check measured values are applicable. Dead line check is performed

for the connected line voltage only.

Note: Please connect the two voltages

always to the terminals R15/R16 and R13/ R14 with the appropriate polarity. The

setting address 106 "Voltage transformer"

must then be set to "single-phase". The

terminals R17 and R18 must not be connected.

The connection of the voltage VL1-L2 as shown in Fig. 10/17 is just an example:

Fig. 10/17 Typical voltage transformer connection for synchro-check with single voltage dead line check

any other of the shown combinations is possible for synchronization.

The two voltage transformer connection

can also be combined with the current

transformer connection according to Fig. 10/16.

15
Siemens SIP · Edition No. 8 10/11

Relays for Various Protection Applications / 7VK61
Technical data

1 2 3 4 5 6 7 8 9 10 11

General unit data

Analog inputs

Rated frequency

50 or 60 Hz (selectable)

Rated current Inom
Rated voltage Vnom
Power consumption With Inom = 1 A With Inom = 5 A Voltage inputs

1 or 5 A (selectable) 80 to 125 V (selectable)
Approx. 0.05 VA Approx. 0.30 VA 0.10 VA

Overload capacity of current circuit

Thermal (r.m.s.)

500 A for 1 s

150 A for 10 s

20 A continuous

Dynamic (peak value)

1250 A (half cycle)

Thermal overload capacity of voltage circuit

230 V continuous

Auxiliary voltage

Rated voltages

DC 24, 48 V DC 60, 125 V DC 110, 250 V and AC 115, 230 V (50/60 Hz)

Permissible tolerance

-20 % to +20 %

Superimposed AC voltage (peak-to-peak)

15 %

Power consumption Quiescent Energized

Approx. 5 W Approx. 8 W to 14 W, depending on design

Bridging time during failure of the auxiliary voltage
For Vaux = 48 V and Vaux 110 V For Vaux = 24 V and Vaux = 60 V

50 ms 20 ms

Binary inputs

Quantity

7VK610

7VK611

Rated voltage range Pickup threshold

24 to 250 V, bipolar DC 19 or 88 V or 176 V, bipolar

Functions are freely assignable

Minimum pickup voltage

DC 19 or 88 V or 176 V, bipolar

Ranges are settable by means of (3 operating ranges)

jumpers for each binary input

Maximum permissible voltage

DC 300 V

Current consumption, energized Approx. 1.8 mA

Input impulse suppression

220 nF coupling capacitance at 220 V with a recovery time >60 ms

Output contacts
"Unit ready" contact (live status contact)
Command/indication relay
Quantity 7VK610 7VK611
NO/NC contact
Switching capacity Make Break, contacts Break, contacts (for resistive load) Break, contacts (for = L/R 50 ms)
Switching voltage
Permissible total current
Operating time, approx. NO contact NO/NC contact (selectable) Fast NO contact
LEDs
Quantity RUN (green) ERROR (red) LED (red), function can be assigned 7VK610 7VK611
Unit design
Housing
Dimensions
Degree of protection acc. to EN 60529
Surface-mounting housing Flush-mounting housing
Front Rear For the terminals
Weight Flush-mounting housing x 19" ½ x 19"
Surface-mounting housing x 19" ½ x 19"

1 NC/NO contact1)
5 NO contacts, 14 NO contacts, 4 NC/NO contacts1)
1000 W/VA 30 VA 40 W
25 VA 250 V 30 A for 0.5 seconds 5 A continuous
8 ms 8 ms 5 ms
1 1
7 14
7XP20 Refer to part 14 for dimension drawings
IP 51 IP 51 IP 50 IP 20 with terminal cover put on
5 kg 6 kg
9.5 kg 11 kg

1) Can be set via jumpers.

10/12 Siemens SIP · Edition No. 8

Relays for Various Protection Applications / 7VK61
Technical data

Electrical tests

Specifications

Standards

IEC 60255 (product standards) IEEE C37.90.0/.1/.2 VDE 0435 For further standards see "Individual tests"

Insulation tests

Standards

IEC 60255-5 and 60870-2-1

Voltage test (100 % test)

All circuits except for auxiliary supply, binary inputs, communication and time synchronization interfaces

2.5 kV (r.m.s.), 50 Hz

Auxiliary voltage and binary inputs (100 % test)

DC 3.5 kV

RS485/RS232 rear side communication interfaces and time synchronization interface (100 % test)

500 V (r.m.s.), 50 Hz

Impulse voltage test (type test) All circuits except for communication interfaces and time synchronization interface, class III

5 kV (peak); 1.2/50 µs; 0.5 J, 3 positive and 3 negative impulses in intervals of 5 s

EMC tests for noise immunity; type tests

Standards

IEC 60255-6; IEC 60255-22 (product standard) EN 61000-6-2 (generic standard), VDE 0435 Part 301, DIN VDE 0435-110

High-frequency test IEC 60255-22-1 class III and VDE 0435 Part 303, class III
Electrostatic discharge IEC 60255-22-2 class IV and EN 61000-4-2, class IV
Irradiation with HF field, IEC 60255-22-3 class III IEC 61000-4-3, class III

2.5 kV (peak); 1 MHz; = 15 µs; 400 surges per s; test duration 2 s; Ri = 200
8 kV contact discharge; 15 kV air discharge; both polarities; 150 pF; Ri = 330
10 V/m; 80 to 1000 MHz; 80 % AM; 1 kHz 10 V/m; 1.4 to 2 GHz; 80 % AM; 1 kHz

Irradiation with HF field, IEC 60255-22-31, IEC 61000-4-3 Amplitude-modulated
Pulse-modulated

Class III, 10 V/m
80; 160; 450; 900 MHz; 80 % AM 1kHz; duration >10 s 900 MHz, 50 % PM, repetition frequency 200 Hz

Fast transient disturbance/bursts IEC 60255-22-4 and IEC 61000-4-4, class IV

4 kV; 5/50 ns; 5 kHz; burst length = 15 ms; repetition rate 300 ms; both polarities; Ri = 50 ; test duration 1 min

EMC tests for noise immunity; type tests

High-energy surge voltages (SURGE),

Impulse: 1.2/50 µs

IEC 61000-4-5 installation class III

Auxiliary supply

Common (longitudinal) mode:

2 kV; 12 ; 9 µF

Differential (transversal) mode: 1 kV; 2 ; 18 µF

Measurement inputs, binary inputs, Common (longitudinal) mode:

2 kV; 42 ; 0.5 µF

binary output relays

Differential (transversal) mode:

1 kV; 42 ; 0.5 µF

Line-conducted HF, amplitude-

10 V; 150 kHz to 80 MHz; 80 % AM;

modulated, IEC 61000-4-6, class III 1 kHz

Magnetic field with power frequen- 30 A/m continuous; 300 A/m for

cy IEC 61000-4-8, class IV; IEC 60255-6

3 s; 50 Hz 0.5 mT; 50 Hz

Oscillatory surge withstand

2.5 kV (peak); 1 MHz; = 50 µs;

capability, IEEE C37.90.1

400 surges per second,

duration 2 s, Ri = 200

Fast transient surge withstand capability, IEEE C37.90.1

4 kV; 5/50 ns; 5 kHz burst length = 15 ms; repetition

rate 300 ms; both polarities;

Ri = 50 ; duration 1 min

Radiated electromagnetic interference IEEE C37.90.2

35 V/m; 25 to 1000 MHz,

Damped oscillation

2.5 kV (peak value); polarity

IEC 60694, IEC 61000-4-12

alternating 100 kHz; 1 MHz; 10 and

50 MHz; Ri = 200

EMC tests for interference emission; type tests

Standard

EN 61000-6-3 (generic standard)

Conducted interference voltage on 150 kHz to 30 MHz

lines, only auxiliary voltage

Limit class B

IEC-CISPR 22 Radio interference field strength

30 to 1000 MHz

IEC-CISPR 22

Limit class B

Harmonic currents on the network Class A limits are observed

lead at AC 230 V, IEC 61000-3-2 Voltage fluctuations and flicker

Limits are observed

on the network incoming feeder at

AC 230 V, IEC 61000-3-3

Mechanical stress test

Vibration, shock stress and seismic vibration

During operation

Standards
Vibration IEC 60255-21-1, class 2 IEC 60068-2-6

IEC 60255-21 and IEC 60068-2
Sinusoidal 10 to 60 Hz: ± 0.075 mm amplitude; 60 to 150 Hz: 1 g acceleration, frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes

Shock IEC 60255-21-2, class 1 IEC 60068-2-27

Half-sinusoidal Acceleration 5 g, duration 11 ms, 3 shocks on each of the 3 axes in both directions

10 11 12 13

1) Conversion with external OLM Fiber-optic interface please complete order number at 11th position with 9 and Order Code L0A (DP RS485) or 9 and Order Code L0G (DNP 3.0) and additionally a suitable external repeater.

14 15
Siemens SIP · Edition No. 8 10/13

Relays for Various Protection Applications / 7VK61
Technical data

Vibration, shock stress and seismic vibration (continued)

Seismic vibration IEC 60255-21-3, class 1

IEC 60068-3-3

During transport

Standards

IEC 60255-21 and IEC 60068-2

Vibration

IEC 60255-21-1, class 2 IEC 60068-2-6

Sinusoidal 5 to 8 Hz: ± 7.5 mm amplitude; 8 to 150 Hz: 2 g acceleration, frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes

Shock

IEC 60255-21-2, class 1 IEC 60068-2-27

Semi-sinusoidal Acceleration 15 g, duration 11 ms, 3 shocks on each of the 3 axes in both directions

Continuous shock

IEC 60255-21-2, class 1 IEC 60068-2-29

Semi-sinusoidal Acceleration 10 g, duration 16 ms, 1000 shocks on each of the 3 axes in both directions

7 8 9 10 11 12

Climatic stress tests
Standard
Temperatures
Type-tested acc. to IEC 60068-2-1 and -2, test Bd, for 16 h
Temporarily permissible operating temperature, tested for 96 h (Legibility of display may be impaired above +55 °C / +131 °F)
Recommended permanent operating temperature acc. to IEC 60255-6
Limiting temperature during permanent storage
Limiting temperature during transport
Humidity
Permissible humidity stress: It is recommended to arrange the units in such a way that they are not exposed to direct sunlight or proounced temperature changes that could cause condensation.

IEC 60255-6
-25 °C to +85 °C / -13 °F to +185 °F -20 °C to +70 °C / -4 °F to +158 °F
-5 °C to +55 °C / +23 °F to +131 °F
-25 °C to +55 °C / -13 °F to 131 °F -25 °C to +70 °C / -13 °F to +158 °F
Annual average on 75 % relative humidity; on 56 days per year up t o 93 % relative humidity; condensation is not permitted.

Futher information can be found in the current manual at: www.siemens.com/siprotec

10/14 Siemens SIP · Edition No. 8

Relays for Various Protection Applications / 7VK61
Selection and ordering data

Description 7VK61 breaker management relay

Housing, binary inputs (BI) and outputs (BO) Housing 19", 7 BI, 6 BO incl. 1 live-status contact, Housing ½ 19", 20 BI, 19 BO incl. 1 live-status contact

Measuring inputs (4 x V, 4 x I) Iph = 1 A, Ie = 1 A (min. = 0.05 A)1) Iph = 5 A, Ie = 5 A (min. = 0.25 A)1)

Rated auxiliary voltage (power supply, threshold of binary inputs) DC 24 to 48 V, binary input threshold 19 V3) DC 60 to 125 V 2), binary input threshold 19 V3) DC 110 to 250 V 2), AC 115 to 230 V, binary input threshold 88 V3) DC 220 to 250 V 2), AC 115 to 230 V, binary input threshold 176 V3)

Unit version For panel flush mounting For panel surface mounting

Region-specific default settings / language settings and functions versions Region DE, language: German, selectable Region World, language: English, selectable Region US, language:US-English, selectable Region FR, language: French, selectable Region World, language: Spanish, selectable Region World, language: Italian, selectable

Port B system interface Empty IEC 60870-5-103 protocol, electrical RS232 IEC 60870-5-103 protocol, electrical RS485 IEC 60870-5-103 protocol, optical 820 nm, ST connector PROFIBUS DP Slave, RS485 PROFIBUS DP Slave, optical 820 nm, double ring, ST connector 4) DNP 3.0, RS485 DNP 3.0, optical 820 nm, ST connector 4) IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector IEC 61850, 100 Mbit Ethernet, optical, double, LC connector 5)

Port C service interface DIGSI 4 / modem, electrical RS232 DIGSI 4 / modem, electrical RS485

Functions Breaker failure protection 1-/3-pole or 3-pole only

Auto-reclosure 1-/3-pole or 3-pole only and synchro-check

Over/Undervoltage protection

Order No. 7VK61 -

Order code

- 4Y 0 -

5
3

5 6

A E
A B C D E F
0 1 2 3 9 9 9 9 9 9
1 2

L 0A L 0 B L 0G L 0H L 0 R L 0 S

9 10

C D

Q R

1) Rated current can be selected by means of jumpers.
2) Transition between the 3 auxiliary ranges can be selected by means of jumpers.
3) The binary input thresholds are selectable in 3 steps by means of jumpers.

4) Optical interfaces are not available with surface mounting housings (position 9 = E). Please order the version with RS485 interface and a separate electrical/optical converter.
5) For surface-mounting housing applications please order the relay with electrical Ethernet interface and use a separate fiber-optic switch.

14 15

Siemens SIP · Edition No. 8 10/15

Relays for Various Protection Applications / 7VK61
Selection and ordering data

Accessories
1
2
3

Description

Order No.

7XV5100-4 3RV1611-1AG14 www.siemens.com/siprotec

Accessories

LSP2289-afp.eps

10 11

Fig. 10/18 Mounting rail for 19" rack

LSP2091-afp.eps

LSP2090-afp.eps

12 13

Fig. 10/19 2-pin connector

Fig. 10/20 3-pin connector

LSP2092-afp.eps

LSP2093-afp.eps

14 15

Fig. 10/21 Short-circuit link for current contacts

Fig. 10/22 Short-circuit link for voltage contacts/ indications contacts

10/16 Siemens SIP · Edition No. 8

Description

Connector

2-pin 3-pin

Order No.
C73334-A1-C35-1 C73334-A1-C36-1

Size of Supplier Fig. package

Siemens 10/19

Siemens 10/20

Crimp connector
Crimping tool

CI2 0.5 to 1 mm2

0-827039-1 0-827396-1

CI2 0.5 to 2.5 mm2

0-827040-1 0-827397-1

Type III+ 0.75 to 1.5 mm2 0-163084-7 0-163083-2

For type III+ and matching female for CI2 and matching female

0-539635-1 0-539668-2 0-734372-1 1-734387-1

4000 1 4000 1 4000 1 1
1

19"-mounting rail

C73165-A63-D200-1 1

Short-circuit For current terminals

links

For other terminals

C73334-A1-C33-1 1 C73334-A1-C34-1 1

Safety cover large for terminals small

C73334-A1-C31-1 1 C73334-A1-C32-1 1

1) 1) 1) 1) 1) 1) 1) 1) 1) 1)
Siemens 10/18
Siemens 10/21 Siemens 10/22
Siemens 10/4 Siemens 10/4

1) Your local Siemens representative can inform you on local suppliers.

Relays for Various Protection Applications / 7VK61
Connection diagrams

Fig. 10/23 Connection diagram 7VK610, x 19" housing Fig. 10/24 Serial interfaces

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 10/17

Relays for Various Protection Applications / 7VK61
Connection diagrams

Fig. 10/25 Connection diagram 7VK611, ½ x 19" housing

10/18 Siemens SIP · Edition No. 8

Generator Protection
SIPROTEC 7UM62 multifunction generator, motor and transformer protection relay SIPROTEC 7VE6 multifunction paralleling device SIPROTEC 7VU683 high speed busbar transfer

Page
11/3 11/33 11/53

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
11/2 Siemens SIP · Edition No. 8

Generator Protection/7UM62
SIPROTEC 7UM62 multifunction generator, motor and transformer protection relay

Function overview

Standard version Scope of basic version plus: · Inadvertent energization protection · 100 %-stator ground-fault protection with 3rd harmonic · Impedance protection

LSP2171-afpen.eps

Full version Scope of standard version plus: · DC voltage protection · Overcurrent protection during start-ups · Ground-current differential protection · Out-of-step protection

Fig. 11/1 SIPROTEC 7UM62 multifunction protection relay for generators, motors and transformers
Description
The SIPROTEC 7UM62 protection relays can do more than just protect. They also offer numerous additional functions. Be it ground faults, short-circuits, overloads, overvoltage, overfrequency or underfrequency asynchronous conditions, protection relays assure continued operation of power stations. The SIPROTEC 7UM62 protection relay is a compact unit which has been specially developed and designed for the protection of small, medium-sized and large generators. They integrate all the necessary protection functions and are particularly suited for the protection of: Hydro and pumped-storage generators Co-generation stations Private power stations using regenerative energy sources such
as wind or biogases Diesel generator stations Gas-turbine power stations Industrial power stations Conventional steam power stations.
The SIPROTEC 7UM62 includes all necessary protection functions for large synchronous and asynchronous motors and for transformers.
The integrated programmable logic functions (continuous function chart CFC) offer the user high flexibility so that adjustments can easily be made to the varying power station requirements on the basis of special system conditions. The flexible communication interfaces are open for modern communication architectures with the control system.
The following basic functions are available for all versions:
Current differential protection for generators, motors and transformers, stator ground-fault protection, sensitive groundfault protection, stator overload protection, overcurrent-time protection (either definite time or inverse time), definite-time overcurrent protection with directionality, undervoltage and overvoltage protection, underfrequency and overfrequency protection, overexcitation and underexcitation protection, external trip coupling, forward-power and reverse-power protection, negative-sequence protection, breaker failure protection, rotor ground-faults protection (fn, R-measuring), motor starting time supervision and restart inhibit for motors.

Additional version Available for each version: · Sensitive rotor ground-fault protection (13 Hz method) · Stator ground-fault protection with 20 Hz voltage · Rate-of-frequency-change protection · Vector jump supervision
Monitoring function · Trip circuit supervision · Fuse failure monitor · Operational measured values V, I, f, ... · Energy metering values Wp, Wq · Time metering of operating hours · Self-supervision of relay · 8 oscillographic fault records
Communication interfaces · System interface
IEC 61850 protocol IEC 60870-5-103 protocol PROFIBUS DP Modbus RTU DNP 3 PROFINET
Hardware
· Analog inputs · 8 current transformers · 4 voltage transformers · 7/15 binary inputs · 12/20 output relays
Front design · User-friendly local operation · 7/14 LEDs for local alarm · Function keys · Graphic display with 7UM623

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 11/3

Generator Protection/7UM62
Application, construction

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Application
The 7UM6 protection relays of the SIPROTEC 4 family are compact multifunction units which have been developed for small to medium-sized power generation plants. They incorporate all the necessary protective functions and are especially suitable for the protection of: Hydro and pumped-storage generators Co-generation stations Private power stations using regenerative energy sources such
as wind or biogases Power generation with diesel generators Gas turbine power stations Industrial power stations Conventional steam power stations.
They can also be employed for protection of motors and transformers.
The numerous other additional functions assist the user in ensuring cost-effective system management and reliable power supply. Measured values display current operating conditions. Stored status indications and fault recording provide assistance in fault diagnosis not only in the event of a disturbance in generator operation.
Combination of the units makes it possible to implement effective redundancy concepts.
Protection functions
Numerous protection functions are necessary for reliable protection of electrical machines. Their extent and combination are determined by a variety of factors, such as machine size, mode of operation, plant configuration, availability requirements, experience and design philosophy.
This results in multifunctionality, which is implemented in outstanding fashion by numerical technology.
In order to satisfy differing requirements, the combination of functions is scalable (see Table 11/3). Selection is facilitated by division into five groups.
Generator Basic
One application concentrates on small and medium generators for which differential protection is required. The function mix is also suitable as backup protection. Protection of synchronous motors is a further application.

generator as well as backup protection for the block transformer including the power system. Additional functions such as protection during start-up for generators with starting converters are also included.The scope of functions can be used for the second protection group, and functions that are not used, can be masked out.
Asynchronous motor
Besides differential protection, this function package includes all protection functions needed to protect large asynchronous motors (more than 1 MVA). Stator and bearing temperatures are measured by a separate thermo-box and are transmitted serially to the protection unit for evaluation.
Transformer
This scope of functions not only includes differential and overcurrent protection, but also a number of protection functions that permit monitoring of voltage and frequency stress, for instance. The reverse-power protection can be used for energy recovery monitoring of parallel-connected transformers.
Construction
The SIPROTEC 4 units have a uniform design and a degree of functionality which represents a whole new quality in protection and control.
Local operation has been designed according to ergonomic criteria. Large, easy-to-read displays were a major design aim. The 7UM623 is equipped with a graphic display thus providing and depicting more information especially in industrial applications. The DIGSI 4 operating program considerably simplifies planning and engineering and reduces commissioning times.
The 7UM621 and 7UM623 are configured in 1/2 19 inches width. This means that the units of previous models can be replaced. The height throughout all housing width increments is 243 mm.
All wires are connected directly or by means of ring-type cable lugs. Alternatively, versions with plug-in terminals are also available. These permit the use of prefabricated cable harnesses.
In the case of panel surface mounting, the connecting terminals are in the form of screw-type terminals at top and bottom. The communication interfaces are also arranged on the same sides.

Generator Standard
In the case of medium-size generators (10 to 100 MVA) in a unit connection, this scope of functions offers all necessary protection functions. Besides inadvertent energization protection, it also includes powerful backup protection for the transformer or the power system. The scope of protection is also suitable for units in the second protection group.

LSP2166-afp.tif

Generator Full
Here, all protection functions are available and the main application focuses on large block units (more than 100 MVA). The function mix includes all necessary protection functions for the

Fig. 11/2 Rear view with wiring terminal safety cover and serial interface

11/4 Siemens SIP · Edition No. 8

Generator Protection/7UM62
Protection functions

Protection functions

Abbreviation ANSI No.

Current differential protection

87G/87T/87M

Stator ground-fault protection non-directional, directional
Sensitive ground-fault protection (also rotor ground-fault protection)

V0>, 3I0> \(V0, 3I0)
IEE>

59N, 64G 67G
50/51GN (64R)

Sensitive ground-fault prot. B (e.g. shaft current prot.) IEE-B> IEE-B<

Stator overload protection

I2t

51GN 49

Definite-time overcurrent prot. with undervolt. seal-in I> +V<

Definite-time overcurrent protection, directional

I>>, Direc.

50/51/67

Inverse-time overcurrent protection

t = f(I)+V<

51V

Overvoltage protection

Undervoltage protection

V<, t = f(V)

Frequency protection

f<, f>

Reverse-power protection

-P

32R

Overexcitation protection (Volt/Hertz)

V/f

Fuse failure monitor External trip coupling

V2/V1, I2/I1 Incoup.

60FL

Trip circuit supervision

T.C.S.

74TC

Forward-power protection

P>, P<

32F

Underexcitation protection (loss-of-field protection) 1/xd

Negative-sequence protection Breaker failure protection Motor starting time supervision Restart inhibit for motors

I2>, t = f(I2) Imin> Istart2t I2t

46 50BF 48 66, 49 Rotor

Rotor ground-fault protection (fn, R-measuring)
Inadvertent energization protection 100 % stator ground-fault protection with 3rd harmonics

R, V< V0 (3rd harm.)

64R (fn)
50/27 59TN, 27TN 3rd h

Impedance protection with (I>+V<) pickup

Interturn protection DC voltage / DC current time protection
Overcurrent protection during startup (for gas turbines)

UInterturn>
Vdc > Idc >
I>

59N(IT)
59N (DC) 51N (DC)
51

Ground-current differential protection Out-of-step protection

Ie Z/t

87GN/TN 78

Rotor ground-fault protection (13 Hz square wave voltage)

RREF<

64R (13 Hz)

100 % stator ground-fault protection with 20 Hz voltage RSEF<

64G (100 %)

Rate-of-frequency-change protection

df/dt >

81R

Vector jump supervision (voltage)

Threshold supervision

Supervision of phase rotation

A, B, C

Undercurrent via CFC

I <

External temperature monitoring via serial interface 1) Optional for all function groups.

(Thermo-box) 38

Generator Basic

4
1)
1)
1) 1) 1)

Generator Standard

Generator Full

Motor Asynchronous

Transformer

Table 11/3 Scope of functions of the 7UM62

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 11/5

Generator Protection/7UM62
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Current differential protection (ANSI 87G, 87M, 87T)

This function provides undelayed shortcircuit protection for generators, motors and transformers, and is based on the current differential protection principle (Kirchhoff's current law).

The differential and restraint (stabilization) current are calculated on the basis of the phase currents. Optimized digital filters reliably attenuate disturbances such as aperiodic component and harmonics. The high resolution of measured quantities permits recording of low differential currents (10 % of IN) and thus a very high sensitivity.

An adjustable restraint characteristic permits optimum adaptation to the conditions of the protected object. Software is used to correct the possible mismatch of the current transformers and the phase angle rotation through the transformer (vector group). Thanks to harmonic analysis of the differential current, inrush (second harmonic) and overexcitation (fifth harmonic) are reliably detected, and unwanted operation of the differential protection is prevented. The current of internal short-circuits is reliably measured by a fast measuring stage (IDiff>>), which operates with two mutually complementary measuring processes. An external short-circuit with transformer saturation is picked up by a saturation detector with time and status monitoring. It becomes active when the differential current (IDiff) moves out of the add-on restraint area.

Fig. 11/3 Restraint characteristic of current differential protection

If a motor is connected, this is detected by monitoring the restraint current and the restraint characteristic is briefly raised. This prevents false tripping in the event of unequal current transmission by the current transformers.

Fig. 11/4 Restraint characteristic of ground-current differential protection

Figure 11/36 shows the restraint characteristic and various areas.
Ground-current differential protection (ANSI 87GN, 87TN)
The ground-current differential protection permits high sensitivity to single-pole faults. The zero currents are compared. On the one hand, the zero-sequence current is calculated on the basis of the phase currents and on the other hand, the ground current is measured directly at the star-point current transformer.
The differential and restraint quantity is generated and fitted into the restraint characteristic (see Fig. 11/37).

DC components in particular are suppressed by means of specially dimensioned filters. A number of monitoring processes avoid unwanted operation in the event of external short-circuits. In the case of a sensitive setting, multiple measurement ensures the necessary reliability.
However, attention must be drawn to the fact that the sensitivity limits are determined by the current transformers.
The protection function is only used on generators when the neutral point is grounded with a low impedance. In the case of transformers, it is connected on the neutral side. Low impedance or solid grounding is also required.

15
11/6 Siemens SIP · Edition No. 8

Generator Protection/7UM62
Protection functions

Definite-time overcurrent protection I>, I>> (ANSI 50, 51, 67)
This protection function comprises the short-circuit protection for the generator and also the backup protection for upstream devices such as transformers or power system protection.
An undervoltage stage at I> maintains the pickup when, during the fault, the current drops below the threshold. In the event of a voltage drop on the generator terminals, the static excitation system can no longer be sufficiently supplied. This is one reason for the decrease of the short-circuit current.
The I>> stage can be implemented as high-set instantaneous trip stage. With the integrated directional function it can be used as backup protection on the transformer high-voltage side. With the information of the directional element, impedance protection can be controlled via the CFC.

Fig. 11/5 Characteristic of negative-sequence protection

Inverse-time overcurrent protection (ANSI 51V)
This function also comprises short-circuit and backup protection and is used for power system protection with current-dependent protection devices.
IEC and ANSI characteristics can be selected (Table 11/4).
The current function can be controlled by evaluating the generator terminal voltage.
The "controlled" version releases the sensitive set current stage.
With the "restraint" version, the pickup value of the current is lowered linearly with decreasing voltage.
The fuse failure monitor prevents unwanted operation.
Stator overload protection (ANSI 49)
The task of the overload protection is to protect the stator windings of generators and motors from high, continuous overload currents. All load variations are evaluated by a mathematical model. The thermal effect of the r.m.s. current value forms the basis of the calculation. This conforms to IEC 60255-8. In dependency of the current, the cooling time constant is automatically extended. If the ambient temperature or the temperature of the coolant are injected via a transducer (TD2) or PROFIBUS DP, the model automatically adapts to the ambient conditions; otherwise a constant ambient temperature is assumed.
Negative-sequence protection (ANSI 46)
Asymmetrical current loads in the three phases of a generator cause a temperature rise in the rotor because of the negativesequence field produced.
This protection detects an asymmetrical load in three-phase generators. It functions on the basis of symmetrical components and evaluates the negative sequence of the phase currents. The thermal processes are taken into account in the algorithm and form the inverse characteristic. In addition, the negative sequence is evaluated by an independent stage (alarm and trip) which is supplemented by a time-delay element (see Fig. 11/38). In the case of motors, the protection function is also used to monitor a phase failure.

Available inverse-time characteristics

Characteristics

ANSI

Inverse

Moderately inverse

Very inverse

Extremely inverse

Definite inverse

Table 11/4

IEC 60255-3 ·
· ·

Underexcitation protection (Loss-of-field protection) (ANSI 40)
Derived from the generator terminal voltage and current, the complex admittance is calculated and corresponds to the generator diagram scaled in per unit. This protection prevents damage due to loss of synchronism resulting from underexcitation. The protection function provides three characteristics for monitoring static and dynamic stability. Via a transducer, the excitation voltage (see Figure 11/52) can be injected and, in the event of failure, a swift reaction of the protection function can be achieved by timer changeover.
The straight-line characteristics allow the protection to be optimally adapted to the generator diagram (see Figure 11/39). The per-unit-presentation of the diagram allows the setting values to be directly read out.
The positive-sequence systems of current and voltage are used to calculate the admittance. This ensures that the protection always operates correctly even with asymmetrical network conditions.
If the voltage deviates from the rated voltage, the admittance calculation has the advantage that the characteristics move in the same direction as the generator diagram.

1 2 3 4 5 6 7 8 9 10 11 12 13 14

15
Siemens SIP · Edition No. 8 11/7

Generator Protection/7UM62
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13

Reverse-power protection (ANSI 32R)
The reverse-power protection monitors the direction of active power flow and picks up when the mechanical energy fails. This function can be used for operational shut-down (sequential tripping) of the generator but also prevents damage to the steam turbines. The reverse power is calculated from the positive-sequence systems of current and voltage. Asymmetrical power system faults therefore do not cause reduced measuring accuracy. The position of the emergency trip valve is injected as binary information and is used to switch between two trip command delays. When applied for motor protection, the sign (±) of the active power can be reversed via parameters.
Forward-power protection (ANSI 32F)
Monitoring of the active power produced by a generator can be useful for starting up and shutting down generators. One stage monitors exceeding of a limit value, while another stage monitors falling below another limit value. The power is calculated using the positive-sequence component of current and voltage. The function can be used to shut down idling motors.

Fig. 11/6 Characteristic of underexcitation protection

Impedance protection (ANSI 21)
This fast short-circuit protection protects the generator and the unit transformer and is a backup protection for the power system. This protection has two settable impedance stages; in addition, the first stage can be switched over via binary input. With the circuit-breaker in the "open" position the impedance measuring range can be extended (see Figure 11/40).
The overcurrent pickup element with undervoltage seal-in ensures a reliable pickup and the loop selection logic ensures a reliable detection of the faulty loop. With this logic it is possible to perform correct measurement via the unit transformer.
Undervoltage protection (ANSI 27)
The undervoltage protection evaluates the positive-sequence components of the voltages and compares them with the threshold values. There are two stages available.
The undervoltage function is used for asynchronous motors and pumped-storage stations and prevents the voltage-related instability of such machines.
The function can also be used for monitoring purposes.
Overvoltage protection (ANSI 59)
This protection prevents insulation faults that result when the voltage is too high.
Either the maximum line-to-line voltages or the phase-to-ground voltages (for low-voltage generators) can be evaluated. The measuring results of the line-to-line voltages are independent of the neutral point displacement caused by ground faults. This function is implemented in two stages.

Fig. 11/7 Grading of impedance protection
Frequency protection (ANSI 81)
The frequency protection prevents impermissible stress of the equipment (e.g. turbine) in case of under or overfrequency. It also serves as a monitoring and control element.
The function has four stages; the stages can be implemented either as underfrequency or overfrequency protection. Each stage can be delayed separately.
Even in the event of voltage distortion, the frequency measuring algorithm reliably identifies the fundamental waves and determines the frequency extremely precisely. Frequency measurement can be blocked by using an undervoltage stage.
Overexcitation protection Volt/Hertz (ANSI 24)
The overexcitation protection serves for detection of an unpermissible high induction (proportional to V/f) in generators or transformers, which leads to thermal overloading. This may occur when starting up, shutting down under full load, with weak systems or under isolated operation. The inverse characteristic can be set via eight points derived from the manufacturer data.
In addition, a definite-time alarm stage and an instantaneous stage can be used. For calculation of the V/f ratio, frequency and also the highest of the three line-to-line voltages are used. The frequency range that can be monitored comprises 11 to 69 Hz.

15
11/8 Siemens SIP · Edition No. 8

Generator Protection/7UM62
Protection functions

90 % stator ground-fault protection, non-directional, directional (ANSI 59N, 64G, 67G)

Ground faults manifest themselves in generators that are operated in isolation by the occurence of a displacement voltage. In case of unit connections, the displacement voltage is an adequate, selective criterion for protection.

For the selective ground-fault detection, the direction of the flowing ground current has to be evaluated too, if there is a direct connection between generator and busbar.
The protection relay measures the displacement voltage at a VT located at the transformer star point or at the broken delta winding of a VT. As an option, it is also possible to calculate the zero-sequence voltage from the phase-to-ground voltages.

Fig. 11/8 Logic diagram of breaker failure protection Breaker failure protection (ANSI 50BF)

Depending on the load resistor selection, 90 to 95 % of the stator winding of a generator can be protected.
A sensitive current input is available for ground-current measurement. This input should be connected to a core-balance current transformer. The fault direction is deduced from the displacement voltage and ground current. The directional characteristic (straight line) can be easily adapted to the system conditions. Effective protection for direct connection of a generator to a busbar can therefore be established. During startup, it is possible to switch over from the directional to the displacement voltage measurement via an externally injected signal.
Depending on the protection setting, various ground-fault protection concepts can be implemented with this function (see Figures 11/51 to 11/54).
Sensitive ground-fault protection (ANSI 50/51GN, 64R)

In the event of scheduled downtimes or a fault in the generator, the generator can remain on line if the circuit-breaker is defective and could suffer substantial damage.
Breaker failure protection evaluates a minimum current and the circuit-breaker auxiliary contact. It can be started by internal protective tripping or externally via binary input. Two-channel activation avoids overfunction (see Figure 11/41).
Inadvertent energization protection (ANSI 50, 27)
This protection has the function of limiting the damage of the generator in the event of an unintentional switch-on of the circuit-breaker, whether the generator is standing still or rotating without being excited or synchronized. If the power system voltage is connected, the generator starts as an asynchronous machine with a large slip and this leads to excessively high currents in the rotor.

The sensitive ground-current input can also be used as separate ground-fault protection. It is of two-stage form. Secondary ground currents of 2 mA or higher can be reliably handled.
Alternatively, this input is also suitable as rotor ground-fault protection. A voltage with rated frequency (50 or 60 Hz) is connected in the rotor circuit via the interface unit 7XR61. If a higher ground current is flowing, a rotor ground fault has occurred. Measuring circuit monitoring is provided for this application (see Figure 11/56).
100 % stator ground-fault protection with 3rd harmonic (ANSI 59TN, 27TN (3rd H.))
Owing to the creative design, the generator produces a 3rd harmonic that forms a zero phase-sequence system. It is verifiable by the protection on a broken delta winding or on the neutral transformer. The magnitude of the voltage amplitude depends on the generator and its operation.
In the event of an ground fault in the vicinity of the neutral point, there is a change in the amplitude of the 3rd harmonic voltage (dropping in the neutral point and rising at the terminals).
Depending on the connection the protection must be set either as undervoltage or overvoltage protection. It can also be delayed. So as to avoid overfunction, the active power and the positive-sequence voltage act as enabling criteria.

A logic circuit consisting of sensitive current measurement for each phase, measured value detector, time control and blocking as of a minimum voltage, leads to an instantaneous trip command. If the fuse failure monitor responds, this function is ineffective.
Rotor ground-fault protection (ANSI 64R)
This protection function can be realized in three ways with the 7UM62. The simplest form is the method of rotor-current measurement (see sensitive ground-current measurement).
Resistance measurement at system-frequency voltage
The second form is rotor ground resistance measurement with voltage at system frequency (see Fig. 11/56). This protection measures the voltage injected and the flowing rotor ground current. Taking into account the complex impedance from the coupling device (7XR61), the rotor ground resistance is calculated by way of a mathematical model. By means of this method, the disturbing influence of the rotor ground capacitance is eliminated, and sensitivity is increased. Fault resistance values up to 30 k can be measured if the excitation voltage is without disturbances. Thus, a two-stage protection function, which features a warning and a tripping stage, can be realized. An additionally implemented undercurrent stage monitors the rotor circuit for open circuit and issues an alarm.

The picked-up threshold of the voltage stage is restrained by the active power. This increases sensitivity at low load.

The final protection setting can be made only by way of a primary test with the generator.

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Generator Protection/7UM62
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Resistance measurement with a square wave voltage of 1 to 3 Hz
A higher sensitivity is required for larger generators. On the one hand, the disturbing influence of the rotor ground capacitance must be eliminated more effectively and, on the other hand, the noise ratio with respect to the harmonics (e.g. sixth harmonic) of the excitation equipment must be increased. Injecting a lowfrequency square wave voltage into the rotor circuit has proven itself excellently here (see Figure 11/57).
The square wave voltage injected through the controlling unit 7XT71 leads to permanent recharging of the rotor ground capacitance. By way of a shunt in the controlling unit, the flowing ground current is measured and is injected into the protection unit (measurement input). In the absence of a fault (RE ), the rotor ground current after charging of the ground capacitance is close to zero. In the event of an ground fault, the fault resistance including the coupling resistance (7XR6004), and also the injecting voltage, defines the stationary current. The current square wave voltage and the frequency are measured via the second input (control input). Fault resistance values up to 80 k can be measured by this measurement principle. The rotor ground circuit is monitored for discontinuities by evaluation of the current during the polarity reversals.
100% stator ground-fault protection with 20 Hz injection (ANSI 64 G (100%))
Injecting a 20 Hz voltage to detect ground faults even at the neutral point of generators has proven to be a safe and reliable method. Contrary to the third harmonic criterion (see page 11/8), it is independent of the generator's characteristics and the mode of operation. Measurement is also possible during system standstill (Fig. 11/56).
This protection function is designed so as to detect both ground faults in the entire generator (genuine 100 %) and all electrically connected system components.
The protection unit measures the injected 20 Hz voltage and the flowing 20 Hz current. The disturbing variables, for example stator ground capacitance, are eliminated by way of a mathematical model, and the ohmic fault resistance is determined.
On the one hand, this ensures high sensitivity and, on the other hand, it permits use of generators with large ground capacitance values, e.g. large hydroelectric generators. Phase-angle errors through the grounding or neutral transformer are measured during commissioning and are corrected in the algorithm.
The protection function has a warning and tripping stage. The measurement circuit is also monitored and failure of the 20 Hz generator is measured.
Independent of ground resistance calculation, the protection function additionally evaluates the amount of the r.m.s. current value.
Starting time supervision (motor protection only) (ANSI 48)
Starting time supervision protects the motor against long unwanted start-ups, which might occur as a result of excessive load torque or excessive voltage drops within the motor, or if the rotor is locked.
The tripping time is dependent on the square of the start-up current and the set start-up time (Inverse Characteristic). It adapts itself to the start-up with reduced voltage. The tripping time is determined in accordance with the following formula:

tTrip

start

Irms

tstart max

tTrip

Tripping time

Istart Permissible start-up current

tstart max Permissible start-up time

Irms

Measured r.m.s. current value

Calculation is not started until the current Irms is higher than an adjustable response value (e.g. 2 IN, MOTOR).

If the permissible locked-rotor time is less than the permissible start-up time (motors with a thermally critical rotor), a binary signal is set to detect a locked rotor by means of a tachometer generator. This binary signal releases the set locked-rotor time, and tripping occurs after it has elapsed.

DC voltage time protection/DC current time protection (ANSI 59N (DC) 51N (DC))
Hydroelectric generators or gas turbines are started by way of frequency starting converters. An ground fault in the intermediate circuit of the frequency starting converter causes DC voltage displacement and thus a direct current. As the neutral or grounding transformers have a lower ohmic resistance than the voltage transformers, the largest part of the direct current flows through them, thus posing a risk of destruction from thermal overloading.
As shown in Fig. 11/55, the direct current is measured by means of a shunt transformer (measuring transducer) connected directly to the shunt. Voltages or currents are fed to the 7UM62 depending on the version of the measuring transducer. The measurement algorithm filters out the DC component and takes the threshold value decision. The protection function is active as from 0 Hz.
If the measuring transducer transmits a voltage for protection, the connection must be interference-free and must be kept short.
The implemented function can also be used for special applications. Thus, the r.m.s. value can be evaluated for the quantity applied at the input over a wide frequency range.

Overcurrent protection during start-up (ANSI 51)
Gas turbines are started by means of frequency starting converters. Overcurrent protection during start-up measures short-circuits in the lower frequency level (as from about 5 Hz) and is designed as independent overcurrent-time protection. The pickup value is set below the rated current. The function is only active during start-up. If frequencies are higher than 10 Hz, sampling frequency correction takes effect and the further short-circuit protection functions are active.

Out-of-step protection (ANSI 78)
This protection function serves to measure power swings in the system. If generators feed to a system short-circuit for too long, low frequency transient phenomena (active power swings) between the system and the generator may occur after fault clearing. If the center of power swing is in the area of the block unit, the "active power surges" lead to unpermissible mechanical stressing of the generator and the turbine.
As the currents and voltages are symmetrical, the positivesequence impedance is calculated on the basis of their positive-sequence components and the impedance trajectory is evaluated. Symmetry is also monitored by evaluation of the

11/10 Siemens SIP · Edition No. 8

Generator Protection/7UM62
Protection functions

between the system owner and the in-plant generator. If the

incoming line fails as the result of auto-reclosure, for instance, a voltage or frequency deviation may occur depending on the

power balance at the feeding generator. Asynchronous condi-

tions may arise in the event of connection, which may lead to

damage on the generator or the gearing between the generator

and the turbine. Besides the classic criteria such as voltage and frequency, the following two criteria are also applied: vector

jump, rate-of-frequency-change protection.

Fig. 11/9 Ranges of the characteristic and possible oscillation profiles

negative-phase-sequence current. Two characteristics in the R/X diagram describe the active range (generator, unit transformer or power system) of the out-of-step protection. The associated counters are incremented depending on the range of the characteristic in which the impedance vector enters or departs. Tripping occurs when the set counter value is reached.
The counters are automatically reset if power swing no longer occurs after a set time. By means of an adjustable pulse, every power swing can be signaled. Expansion of the characteristic in the R direction defines the power swing angle that can be measured. An angle of 120 ° is practicable. The characteristic can be tilted over an adjustable angle to adapt to the conditions prevailing when several parallel generators feed into the system.

Inverse undervoltage protection (ANSI 27)

Motors tend to fall out of step when their torque is less than the breakdown torque. This, in turn, depends on the voltage. On the one hand, it is desirable to keep the motors connected to the system for as long as possible while, on the other hand, the torque should not fall below the breakdown level. This protection task is realized by inverse undervoltage protection. The inverse characteristic is started if the voltage is less than the pickup threshold Vp<. The tripping time is inversely proportional to the voltage dip (see equation). The protection function uses the positive-sequence voltage, for the protection decision.

tTRIP

I -V

tTRIP

Tripping time

Voltage

Pickup value

Time multiplier

System disconnection
Take the case of in-plant generators feeding directly into a system. The incoming line is generally the legal entity boundary

Rate-of-frequency-change protection (ANSI 81)
The frequency difference is determined on the basis of the calculated frequency over a time interval. It corresponds to the momentary rate-of-frequency change. The function is designed so that it reacts to both positive and negative rate-of-frequency changes. Exceeding of the permissible rate-of-frequency change is monitored constantly. Release of the relevant direction depends on whether the actual frequency is above or below the rated frequency. In total, four stages are available, and can be used optionally.
Vector jump
Monitoring the phase angle in the voltage is a criterion for identifying an interrupted infeed. If the incoming line should fail, the abrupt current discontinuity leads to a phase angle jump in the voltage. This is measured by means of a delta process. The command for opening the generator or coupler circuit-breaker is issued if the set threshold is exceeded.
Restart inhibit for motors (ANSI 66, 49Rotor)
When cold or at operating temperature, motors may only be connected a certain number of times in succession. The start-up current causes heat development in the rotor which is monitored by the restart inhibit function.
Contrary to classical counting methods, in the restart inhibit function the heat and cooling phenomena in the rotor are simulated by a thermal replica. The rotor temperature is determined on the basis of the stator currents. Restart inhibit permits restart of the motor only if the rotor has enough thermal reserve for a completely new start. Fig.11/43 illustrates the thermal profile for a permissible triple start out of the cold state. If the thermal reserve is too low, the restart inhibit function issues a blocking signal with which the motor starting circuit can be blocked. The blockage is canceled again after cooling down and the thermal value has dropped below the pickup threshold.
As the fan provides no forced cooling when the motor is off, it cools down more slowly. Depending on the operating state, the protection function controls the cooling time constant. A value below a minimum current is an effective changeover criterion.

3 4 5 6 7 8 9 10 11 12

Sensitive ground-fault protection B (ANSI 51 GN)
The IEE-B sensitive ground-fault protection feature of 7UM62 provides greater flexibility and can be used for the following applications:
· Any kind of ground-fault current supervision to detect ground faults (fundamental and 3rd harmonics)
· Protection against load resistances
· Shaft current protection in order to detect shaft currents of the generator shaft and prevent that bearings take damage.
The sensitive ground-current protection IEE-B uses either the hardware input IEE1 or IEE2. These inputs are designed in a way that

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Generator Protection/7UM62
Protection functions

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

allows them to cut off currents greater than 1.6 A (thermal limit, see technical data). This has to be considered for the applications or for the selection of the current transformers.

The shaft current protection function is of particular interest in conjunction with hydroelectric generators. Due to their construction, the hydroelectric generators have relatively long shafts. A number of factors such as friction, magnetic fields of the generators and others can build up a voltage across the shaft which then acts as voltage source (electromotive force-emf). This inducted voltage of approx. 10 to 30 V is dependent on the load, the system and the machine.

If the oil film covering a bearing is too

thin, breakdown can occur. Due to the low

resistance (shaft, bearing and grounding),

high currents may flow that destroy the bear-

ing. Past experience has shown that currents

greater than 1 A are critical for the bearings.

Fig. 11/10 Temperature characteristic at rotor and thermal replica of the rotor

As different bearings can be affected, the cur-

(multiple start-ups)

rent entering the shaft is detected by means

of a special transformer (folding transformer).

Phase rotation reversal

Interturn protection (ANSI 59N (IT))

If the relay is used in a pumped-storage power plant, matching

The interturn fault protection detects faults between turns

to the prevailing rotary field is possible via a binary input (gen-

within a generator winding (phase). This situation may involve erator/motor operation via phase rotation reversal).

relatively high circulating currents that flow in the shortcircuited turns and damage the winding and the stator. The

2 pre-definable parameter groups

protection function is characterized by a high sensitivity.

In the protection, the setting values can be stored in two data

The displacement voltage is measured at the open delta winding by means of 3 two-phase isolated voltage transformers. So as to be insensitive towards ground faults, the isolated voltage transformer star point has to be connected to the generator star point

sets. In addition to the standard parameter group, the second group is provided for certain operating conditions (pumpedstorage power stations). It can be activated via binary input, local control or DIGSI 4.

by means of a high-voltage cable. The voltage transformer star point must not be grounded since this implies that the generator Lockout (ANSI 86)

star point, too, would be grounded with the consequence that each fault would lead to a single-pole ground fault.

All binary outputs (alarm or trip relays) can be stored like LEDs and reset using the LED reset key. The lockout state is also stored

In the event of an interturn fault, the voltage in the affected phase will be reduced causing a displacement voltage that is

in the event of supply voltage failure. Reclosure can only occur after the lockout state is reset.

detected at the broken delta winding. The sensitivity is limited rather by the winding asymmetries than by the protection unit.

Fuse failure and other monitoring

An FIR filter determines the fundamental component of the voltage based an the scanned displacement voltage. Selecting

The relay comprises high-performance monitoring for the hardware and software.

an appropriate window function has the effect that the sensitiv- The measuring circuits, analog-digital conversion, power supply

ity towards higher-frequency oscillations is improved and the

voltages, memories and software sequence (watch-dog) are all

disturbing influence of the third harmonic is eliminated while

monitored.

achieving the required measurement sensitivity.

The fuse failure function detects failure of the measuring voltage

External trip coupling
For recording and processing of external trip information, there are 4 binary inputs. They are provided for information from the Buchholz relay or generator-specific commands and act like a protection function. Each input initiates a fault event and can be

due to short-circuit or open circuit of the wiring or VT and avoids overfunction of the undervoltage elements in the protection functions.
The positive and negative-sequence system (voltage and current) are evaluated.

individually delayed by a timer.

Filter time

All binary inputs can be subjected to a filter time (indication suppression).

11/12 Siemens SIP · Edition No. 8

Generator Protection/7UM62
Communication

Communication

With respect to communication, particular emphasis has been

placed on high levels of flexibility, data integrity and utilization

of standards common in energy automation. The design of

the communication modules permits interchangeability on the one hand, and on the other hand provides openness for future

standards (for example, Industrial Ethernet).

Local PC interface

The PC interface accessible from the front of the unit permits

quick access to all parameters and fault event data. The use

of the DIGSI 4 operating program during commissioning is

particularly advantageous.

Rear-mounted interfaces

Two communication modules on the rear of the unit incorporate Fig. 11/11 IEC 60870-5-103 star-type RS232 copper conductor

optional equipment complements and permit retrofitting. They

connection or fiber-optic connection

assure the ability to comply with the requirements of different

communication interfaces (electrical or optical) and protocols

(IEC 60870, PROFIBUS, DIGSI).

The interfaces make provision for the following applications:

Service interface (fixed)

In the RS485 version, several protection units can be centrally

operated with DIGSI 4. By using a modem, remote control is possible. This provides advantages in fault clearance, in particular in

unmanned substations.

System interface

This is used to communicate with a control or protection

and control system and supports, depending on the module

connected, a variety of communication protocols and interface

designs. Furthermore, the units can exchange data through this

interface via Ethernet and IEC 61850 protocol and can also be operated by DIGSI.

IEC 61850 protocol
The Ethernet-based IEC 61850 protocol is the worldwide standard for protection and control systems used by power supply corporations. Siemens is of the first manufacturer to support this standard. By means of this protocol, information can also be exchanged directly between bay units so as to set up simple masterless systems for bay and system interlocking. Access to the units via the Ethernet bus will also be possible with DIGSI.
IEC 60870-5-103
IEC 60870-5-103 is an internationally standardized protocol for communication in the protected area.
IEC 60870-5-103 is supported by a number of protection unit manufacturers and is used worldwide.
The generator protection functions are stored in the manufacturer-specific, published part of the protocol.
PROFINET
PROFINET is the ethernet-based successor of Profi bus DP and is supported in the variant PROFINET IO. The protocol which is used in industry together with the SIMATIC systems control is realized on the optical and electrical Plus ethernet modules which are delivered since November 2012. All network redun-

Fig. 11/12 B us structure for station bus with Ethernet and IEC 61850, fiber-optic ring

dancy procedures which are available for the ethernet modules, such as RSTP, PRP or HSR, are also available for PROFINET.
The time synchronization is made via SNTP. The network monitoring is possible via SNMP V2 where special MIB files exist for PROFINET. The LLDP protocol of the device also supports the monitoring of the network topology. Single-point indications, double-point indications, measured and metered values can be transmitted cyclically in the monitoring direction via the protocol and can be selected by the user with DIGSI 4. Important events are also transmitted spontaneously via confi gurable process alarms. Switching commands can be executed by the system control via the device in the controlling direction.
The PROFINET implementation is certified. The device also supports the IEC 61850 protocol as a server on the same ethernet module in addition to the PROFINET protocol. Client server connections are possible for the intercommunication between devices, e.g. for transmitting fault records and GOOSE messages.

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Siemens SIP · Edition No. 8 11/13

Generator Protection/7UM62
Communication

1 2 3 4 5 6 7 8 9 10

PROFIBUS DP
PROFIBUS is an internationally standardized communication protocol (EN 50170). PROFIBUS is supported internationally by several hundred manufacturers and has to date been used in more than 1,000,000 applications all over the world.
With the PROFIBUS DP, the protection can be directly connected to a SIMATIC S5/S7. The transferred data are fault data, measured values and information from or to the logic (CFC).
MODBUS RTU
MODBUS is also a widely utilized communication standard and is used in numerous automation solutions.

Fig. 11/13 RS232/RS485 Electrical communication module

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 2 compliant with DNP 3.0. DNP 3.0 is supported by a number of protection device manufacturers.
Safe bus architecture
· RS485 bus With this data transmission via copper conductors, electromagnetic interference influences are largely eliminated by the use of twisted-pair conductor. Upon failure of a unit, the remaining system continues to operate without any faults.
· Fiber-optic double ring circuit The fiber-optic double ring circuit is immune to electromagnetic interference. Upon failure of a section between two units, the communication system continues to operate without disturbance.

Fig. 11/15 PROFIBUS communication module optical, double-ring

LSP2164-afpen.tif LSP3.01-0021.eps

LSP2163-afpen.tif LSP2162-afpen.tif

Fig. 11/14 820 nm fiber-optic communication module
Fig. 11/16 Optical Ethernet communication module for IEC 61850 with integrated Ethernet switch

11 12 13 14 15

System solution
SIPROTEC 4 is tailor-made for use in SIMATICbased automation systems.
Via the PROFIBUS DP, indications (pickup and tripping) and all relevant operational measured values are transmitted from the protection unit.
Via modem and service interface, the protection engineer has access to the protection devices at all times. This permits remote maintenance and diagnosis (cyclic testing).
Parallel to this, local communication is possible, for example, during a major inspection.
For IEC 61850, an interoperable system solution is offered with SICAM PAS. Via the 100 Mbit/s Ethernet bus, the unit are linked with PAS electrically or optically to the station PC. The interface is standardized, thus also

Fig. 11/17 System solution: Communications
enabling direct connection of units of other manufacturers to the Ethernet bus. With IEC 61850, however, the units can also be used in other manufacturers' systems (see Fig. 11/45).
Analog output 0 to 20 mA Alternatively to the serial interfaces up to two analog output modules (4 channels) can be installed in the 7UM62. Several operational measured values (I1, I2, V, P, Q, f, PF (cos ), stator, rotor) can be selected and transmitted via the 0 to 20 mA interfaces.

11/14 Siemens SIP · Edition No. 8

Typical connections
Direct generator busbar connection
Figure 11/51 illustrates the recommended standard connection when several generators supply one busbar. Phase-to-ground faults are disconnected by employing the directional ground-fault criterion. The ground-fault current is driven through the cables of the system. If this is not sufficient, an grounding transformer connected to the busbar supplies the necessary current (maximum approximately 10 A) and permits a protection range of up to 90 %. The ground-fault current should be detected by means of core-balance current transformers in order to achieve the necessary sensitivity. The displacement voltage can be used as ground-fault criterion during starting operations until synchronization is achieved.
Differential protection embraces protection of the generator and of the outgoing cable. The permissible cable length and the current transformer design (permissible load) are mutually dependent. Recalculation is advisable for lengths of more than 100 m.

Generator Protection/7UM62
Typical connections
1 2 3 4 5 6 7 8

Fig. 11/18

13 14

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Siemens SIP · Edition No. 8 11/15

Generator Protection/7UM62
Typical connections

Direct generator busbar connection

with low-resistance grounding If the generator neutral point has low-

resistance grounding, the connection illus-

trated in Fig. 11/52 is recommended. In the

case of several generators, the resistance must be connected to only one generator,

in order to prevent circulating currents

(3rd harmonic).

For selective ground-fault detection, the ground-current input should be looped

into the common return conductor of the

two current transformer sets (differential

connection). The current transformers must be grounded at only one point. The

displacement voltage VE is utilized as an

additional enabling criterion.

Balanced current transformers (calibration of windings) are desirable with this form of

connection. In the case of higher generator

power (for example, IN approximately

2000 A), current transformers with a secondary rated current of 5 A are recom-

mended.

Ground-current differential protection can

be used as an alternative (not illustrated).

10 11

Fig. 11/19

15
11/16 Siemens SIP · Edition No. 8

Unit connection with isolated star point
This configuration of unit connection is a variant to be recommended (see Fig. 11/53). Ground-fault detection is effected by means of the displacement voltage. In order to prevent unwanted operation in the event of ground faults in the system, a load resistor must be provided at the broken delta winding. Depending on the plant (or substation), a voltage transformer with a high power (VA) may in fact be sufficient. If not, an grounding transformer should be employed. The available measuring winding can be used for the purpose of voltage measurement.
In the application example, differential protection is intended for the generator. The unit transformer is protected by its own differential relay (e.g. 7UT612).
As indicated in the figure, additional protection functions are available for the other inputs. They are used on larger generator/ transformer units (see also Figures 11/56 and 11/58).

Generator Protection/7UM62
Typical connections
1 2 3 4 5 6 7

Fig. 11/20

12 13

15
Siemens SIP · Edition No. 8 11/17

Generator Protection/7UM62
Typical connections

Unit connection with neutral

transformer With this system configuration, disturbance

voltage reduction and damping in the

event of ground faults in the generator

area are effected by a load resistor connected to the generator neutral point.

The maximum ground-fault current is lim-

ited to approximately 10 A. Configuration

can take the form of a primary or secondary resistor with neutral transformer. In

order to avoid low secondary resistance,

the transformation ratio of the neutral

transformer should be below

VGen

500 V

The higher secondary voltage can be reduced by means of a voltage divider.

Electrically, the circuit is identical to the

configuration in Fig. 11/53.

In the application opposite, the differential

protection is designed as an overall func-

tion and embraces the generator and unit

transformer. The protection function carries

out vector group adaptation as well as

other adaptations.

Fig. 11/21

15
11/18 Siemens SIP · Edition No. 8

Generator Protection/7UM62
Typical connections

Voltage transformer in open delta connection (V-connection)
Protection can also be implemented on voltage transformers in open delta connection (Fig. 11/55). If necessary, the operational measured values for the phase-to-ground voltages can be slightly asymmetrical. If this is disturbing, the neutral point (R16) can be connected to ground via a capacitor.
In the case of open delta connection, it is not possible to calculate the displacement voltage from the secondary voltages. It must be passed to the protection relay along a different path (for example, voltage transformer at the generator neutral point or from the grounding transformer).
100 % stator ground-fault protection, ground-fault protection during start-up
Fig. 11/56 illustrates the interfacing of 100 % stator ground-fault protection with voltage injection of 20 Hz, as meant for the example of the neutral transformer. The same interfacing connection also applies to the broken delta winding of the grounding transformer.
The 20 Hz generator can be connected both to the DC voltage and also to a powerful voltage transformer (>100 VA). The load of the current transformer 4NC1225 should not exceed 0.5 .
The 7XT33, 7XT34 and load resistance connection must be established with a low resistance (RConnection < RL). If large distances are covered, the devices are accommodated in the grounding cubicle.
Connection of the DC voltage protection function (TD 1) is shown for systems with a starting converter. Depending on the device selection, the 7KG6 boosts the measured signal at the shunt to 10 V or 20 mA.
The TD 1 input can be jumpered to the relevant signal.

Fig. 11/22

Fig. 11/23

1 2 3 4 5 6 7 8 9 10 11 12

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Siemens SIP · Edition No. 8 11/19

Generator Protection/7UM62
Typical connections

Rotor ground-fault protection with volt-

age injection at rated frequency Fig. 11/57 shows the connection of rotor

ground-fault protection to a generator with

static excitation. If only the rotor current

is evaluated, there is no need for voltage connection to the relay.

Ground must be connected to the ground-

ing brush. The external resistors 3PP1336

must be added to the coupling device 7XR61 if the circulating current can exceed

0.2 A as the result of excitation (sixth

harmonic). This is the case as from a rated

excitation voltage of >150 V, under worstcase conditions.

Fig. 11/24

Rotor ground-fault protection with a

square wave voltage of 1 to 3 Hz

The measuring transducers TD1 and TD2

are used for this application. The control-

ling unit 7XT71 generates a square wave

voltage of about ± 50 V at the output. The

frequency can be jumpered and depends

on the rotor ground capacitance. Voltage polarity reversal is measured via the control

input and the flowing circular current is

measured via the measurement input.

Ground must be connected to the grounding brush.

Fig. 11/25

15
11/20 Siemens SIP · Edition No. 8

Protection of an asynchronous motor
Fig. 11/59 shows a typical connection of the protection function to a large asynchronous motor. Differential protection embraces the motor including the cable. Recalculation of the permissible current transformer burden is advisable for lengths of more than 100 m.
The voltage for voltage and displacement voltage monitoring is generally tapped off the busbar. If several motors are connected to the busbar, ground faults can be detected with the directional ground-fault protection and selective tripping is possible. A core balance current transformer is used to detect the ground current. The chosen pickup value must be slightly higher if there are several cables in parallel.
The necessary shut-down of the motor in the event of idling can be realized with active power monitoring.

Generator Protection/7UM62
Typical connections
1 2 3 4 5 6

Fig. 11/26

12 13

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Siemens SIP · Edition No. 8 11/21

Generator Protection/7UM62
Typical connections

1 2 3 4 5 6 7 8 9 10 11

Use of selected analog inputs
Several protection functions take recourse to the same analog inputs, thus ruling out certain functions depending on the application. One input may only be used by one protection function. A different combination can be used by the unit belonging to Protection Group 2, for example.
Multiple use refers to the sensitive groundcurrent inputs and the displacement voltage input (see Table 11/5).
The same applies to the measuring transducers (Table 11/6).
Current transformer requirements
The requirements imposed on the current transformer are determined by the differential protection function. The instantaneous trip stage (IDiff>>) reliably masters (via the instantaneous algorithm) any high-current internal short-circuits.
The external short-circuit determines the requirements imposed on the current transformer as a result of the DC component. The non-saturated period of a flowing short-circuit current should be at least 5 ms. Table 11/7 shows the design recommendations.
IEC 60044-1 and 60044-6 were taken into account. The necessary equations are shown for converting the requirements into the knee- point voltages. The customary practice which presently applies should also be used to determine the rated primary current of the current transformer rated current. It should be greater than or equal to the rated current of the protected object.

IEE1

IEE2

Sensitive ground-fault protection

Directional stator ground-fault protection

Rotor ground-fault protection (fn, R-measuring)

100 % stator ground-fault protection with 20 Hz voltage

Ground-current differential protection

1) optional (either IEE1 or IEE2)

Table 11/5 Multiple use of analog inputs

Injection of excitation voltage DC voltage time/DC current time protection Injection of a temperature Rotor ground-fault protection (1 to 3 Hz) Processing of analog values via CFC
Table 11/6 Multiple use of measuring transducers

TD1

TD2

TD3

Symmetrical short-circuit limiting factor
Required actual accuracy limiting factor IpSC
K´SSC = Ktd· Ipn

Resulting rated accuracy limiting factor

K SSC

Rb + RCT RBN + RCT

KSSC

Current transformer requirements

Transient dimensioning factor Ktd Symmetrical short-circuit current Ipssc
Example
Note: Identical transformers have to be employed

Transformer

4 N 100 ms

1 v sc

Ipn,

vsc = 0.1 K'ssc > 40
Rated power 10 or 15 VA
Example: Network transformer 10P10: (10 or 15) VA (Isn = 1 or 5 A)

Generator

> (4 to 5) N > 100 ms

1 x"d

Ipn,

x"d = 0.12 K'ssc > (34 to 42)
Note: Secondary winding resistance
Example: IN, G approx. 1000 to 2000 A 5P15: 15 VA (Isn = 1 or 5 A)
IN, G > 5 000 A 5P20: 30 VA (Isn = 1 or 5 A)

12 13 14 15

Knee-point voltage

IEC

British Standard

ANSI

( ) V = K SSC Rct + Rb ISN

( ) V =

Rct

+ Rb 1.3

I SN K SSC

( ) V = 20 ISN

Rct

+ Rb

K SSC 20

Isn = 5A (typical value)

Ktd Rated transient dimensioning factor Ipssc Primary symmetrical short-circuit current Ipn Rated primary current (transformer) R'b Connected burden Rb Rated resistive burden

Rct Secondary winding resistance vsc Short-circuit voltage (impedance voltage) x"d Subtransient reactance Isn Rated secondary current (transformer) tN Network time constant

Table 11/7 Multiple use of measuring transducers

11/22 Siemens SIP · Edition No. 8

Generator Protection/7UM62
Technical data

General unit data

Analog inputs

Rated frequency

50 or 60 Hz

Rated current IN Ground current, sensitive IEmax Rated voltage VN Measuring transducer
Power consumption With IN = 1 A With IN = 5 A For sensitive ground current Voltage inputs (with 100 V)

1 or 5 A 1.6 A 100 to 125 V - 10 to + 10 V (Ri=1 M) or - 20 to + 20 mA (Ri = 10 )
Approx. 0.05 VA Approx. 0.3 VA Approx. 0.05 VA Approx. 0.3 VA

Capability in CT circuits Thermal (r.m.s. values)
Dynamic (peak) Ground current, sensitive
Dynamic (peak)

100 IN for 1 s 30 IN for 10 s 4 IN continuous
250 IN (one half cycle)
300 A for 1 s 100 A for 10 s 15 A continuous 750 A (one half cycle)

Capability in voltage paths

230 V continuous

Capability of measuring transducer

As voltage input

60 V continuous

As current input

100 mA continuous

Auxiliary voltage

Rated auxiliary voltage

DC 24 to 48 V DC 60 to 125 V DC 110 to 250 V and AC 115 V/230 V with 50/60 Hz

Permitted tolerance

20 to +20 %

Superimposed (peak-to-peak)

15 %

Power consumption During normal operation 7UM621 7UM622 7UM623 During pickup with all inputs and outputs activated 7UM611 7UM612 7UM623

Approx. 5.3 W Approx. 5.5 W Approx. 8.1 W
Approx. 12 W Approx. 15 W Approx. 14.5 W

Bridging time during auxiliary voltage failure
at Vaux = 48 V and Vaux 110 V at Vaux = 24 V and Vaux = 60 V

50 ms 20 ms

Binary inputs

Number

7UM621, 7UM623

7UM622

3 pickup thresholds

DC 10 to 19 V or DC 44 to 88 V

Range is selectable with jumpers DC 88 to 176 V1)

Maximum permissible voltage

DC 300 V

Current consumption, energized Approx. 1.8 mA

Output relays Number
7UM621
7UM622
Switching capacity Make Break Break (for resistive load) Break (for L/R 50 ms)
Switching voltage Permissible current
LEDs Number
RUN (green) ERROR (red) Assignable LED (red)
Unit design 7XP20 housing
Degree of protection acc. to EN 60529
For surface-mounting housing For flush-mounting housing
Front Rear For the terminals Weight Flush mounting housing 7UM621 (½ x 19") 7UM622 (1 x 19") Surface mounting housing 7UM621 (½ x 19") 7UM622 (1 19")

12 (1 NO, 4 optional as NC, via jumper) 21 (1 NO, 5 optional as NC, via jumper)
1000 W / VA 30 VA 40 W 25 VA 250 V 5 A continuous 30 A for 0.5 seconds
1 1 14
For dimensions see dimension drawings, part 14
IP 51
IP 51 IP 50 IP 2x with terminal cover put on
Approx. 7 kg Approx. 9.5 kg
Approx. 12 kg Approx. 15 kg

Electrical tests

Specifications

Standards

IEC 60255 (product standards) ANSI/IEEE C37.90.0/.1/.2 UL 508 DIN 57435, part 303 For further standards see below

Insulation tests

Standards

IEC 60255-5

Voltage test (routine test)

2.5 kV (r.m.s.), 50 Hz

All circuits except for auxiliary sup-

ply, binary inputs communication

and time synchronization interfaces

Voltage test (routine test)

3.5 kV

Auxiliary voltage and binary inputs

Voltage test (routine test)

500 V (r.m.s. value), 50 Hz

only isolated communication

interfaces and time synchronization

interface

Impulse voltage test (type test) 5 kV (peak); 1.2/50 s; 0.5 J; All circuits except for communication 3 positive and 3 negative impulses interfaces and time synchronization at intervals of 1 s interface, class III

1 2 3 4 5 6 7 8 9 10 11 12 13 14

15
Siemens SIP · Edition No. 8 11/23

Generator Protection/7UM62
Technical data

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

EMC tests for noise immunity; type test

Standards

IEC 60255-6, IEC 60255-22 (product standards) EN 50082-2 (generic standard) DIN 57435 part 303

High frequency test IEC 60255-22-1, class III and DIN 57435 part 303, class III

2.5 kV (peak value), 1 MHz; = 15 ms 400 pulses per s; duration 2 s

Electrostatic discharge IEC 60255-22-2 class IV EN 61000-4-2, class IV
Irradiation with RF field, non-modulated IEC 60255-22-3 (report), class III

8 kV contact discharge; 15 kV air discharge; both polarities; 150 pF; Ri = 330
10 V/m; 27 to 500 MHz

Irradiation with RF field, amplitude- 10 V/m; 80 to 1000 MHz; 80 % AM; modulated, IEC 61000-4-3, class III 1 kHz

Irradiation with RF field,

10 V/m; 900 MHz; repetition

pulse-modulated

frequency 200 Hz; duty cycle 50 %

IEC 61000-4-3/ ENV 50204, class III

Fast transient interference bursts IEC 60255-22-4, IEC 61000-4-4, class IV
High-energy surge voltages (SURGE), IEC 61000-4-5 installation, class III Auxiliary supply

4 kV; 5/50 ns; 5 kHz; burst length = 15 ms; repetition rate 300 ms; both polarities; Ri = 50 ; test duration 1 min Impulse: 1.2/50 s
Common (longitudinal) mode: 2 kV; 12 , 9 F Differential (transversal) mode: 1 kV; 2 , 18 F

Measurement inputs, binary inputs Common (longitudinal) mode:

and relay outputs

2 kV; 42 , 0.5 F

Differential (transversal) mode:

1 kV; 42 , 0.5 F

Line-conducted HF, amplitude-modulated IEC 61000-4-6, class III

10 V; 150 kHz to 80 MHz; 80 % AM; 1 kHz

Magnetic field with power frequency IEC 61000-4-8, class IV; IEC 60255-6

30 A/m continuous; 300 A/m for 3 s; 50 Hz 0.5 mT; 50 Hz

Oscillatory surge withstand capability ANSI/IEEE C37.90.1
Fast transient surge withstand capability ANSI/IEEE C37.90.1
Radiated electromagnetic interference ANSI/IEEE C37.90.2

2.5 to 3 kV (peak); 1 to 1.5 MHz damped wave; 50 surges per second; duration 2 s; Ri = 150 to 200
4 to 5 kV; 10/150 ns; 50 surges per second; both polarities; duration 2 s; Ri = 80
35 V/m; 25 to 1000 MHz

Damped oscillations IEC 60894, IEC 61000-4-12

2.5 kV (peak value), polarity alternating 100 kHz, 1 MHz, 10 and 50 MHz, Ri = 200

EMC tests for interference emission; type tests

Standard

EN 50081-x (generic standard)

Conducted interference voltage on lines only auxiliary supply IEC-CISPR 22

150 kHz to 30 MHz Limit class B

Interference field strength IEC-CISPR 22

30 to 1000 MHz Limit class B

1) Conversion with external OLM For fiber-optic interface please complete order number at 11th position with 4 (FMS RS485) or 9 and Order code L0A (DP RS485) and additionally order: For single ring: SIEMENS OLM 6GK1502-3AB10 For double ring: SIEMENS OLM 6GK1502-4AB10

11/24 Siemens SIP · Edition No. 8

Mechanical stress tests

Vibration, shock stress and seismic vibration

During operation

Standards

IEC 60255-21 and IEC 60068

Vibration IEC 60255-21-1, class 2 IEC 60068-2-6

Sinusoidal 10 to 60 Hz: ± 0.075 mm amplitude; 60 to 150 Hz: 1 g acceleration Frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes

Shock IEC 60255-21-2, class 1 IEC 60068-2-27

Half-sinusoidal Acceleration 5 g, duration 11 ms, 3 shocks each in both directions of the 3 axes

Seismic vibration IEC 60255-21-2, class 1 IEC 60068-3-3

During transport

Standards

IEC 60255-21 and IEC 60068-2

Vibration IEC 60255-21-1, class 2 IEC 60068-2-6

Sinusoidal 5 to 8 Hz: ±7.5 mm amplitude; 8 to 150 Hz: 2 g acceleration Frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes

Shock IEC 60255-21-2, class 1 IEC 60068-2-27

Half-sinusoidal Acceleration 15 g, duration 11 ms, 3 shocks each in both directions 3 axes

Continuous shock IEC 60255-21-2, class 1 IEC 60068-2-29

Half-sinusoidal Acceleration 10 g, duration 16 ms, 1000 shocks in both directions of the 3 axes

Climatic stress test
Temperatures
Type-tested acc. to IEC 60068-2-1 and -2, test Bd, for 16 h
Temporarily permissible operating temperature, tested for 96 h
Recommended permanent operating temperature acc. to IEC 60255-6 (Legibility of display may be impaired above +55 °C / +131 °F)
Limiting temperature during permanent storage
Limiting temperature during transport
Humidity
Permissible humidity stress It is recommended to arrange the units in such a way that they are not exposed to direct sunlight or pronounced temperature changes that could cause condensation

25 °C to +85 °C / 13 °F to +185 °F 20 °C to +70 °C / 4 °F to +158 °F 5 °C to +55 °C / +25 °F to +131 °F
25 °C to +55 °C / 13 °F to +131 °F 25 °C to +70 °C / 13 °F to +158 °F
Annual average 75 % relative humidity; on 56 days a year up to 93 % relative humidity; condensation is

Futher information can be found in the current manual at: www.siemens.com/siprotec

Generator Protection/7UM62
Selection and ordering data

Description 7UM62 multifunction generator, motor and transformer protection relay

Order No.

Order code

7UM62 - - 0-

Housing, binary inputs and outputs Housing ½ 19", 7 BI, 12 BO, 1 live status contact Housing 19", 15 BI, 20 BO, 1 live status contact Graphic display, ½ 19'', 7 BI, 12 BO, 1 live status contact

Continued

on next page

Current transformer IN

1 A1), IEE (sensitive)

5 A1), IEE (sensitive)

Rated auxiliary voltage (power supply, indication voltage)

DC 24 to 48 V, threshold binary input 19 V3)

DC 60 to 125 V2), threshold binary input 19 V3)

DC 110 to 220 V2), AC 115 V/230 V, threshold binary input 88 V3)

DC 220 to 250 V, AC 115 V/230 V, threshold binary input 176 V

Unit version

For panel surface-mounting, 2 tier screw-type terminals top/bottom

For panel flush-mounting, plug-in terminals (2-/3- pin connector)

Flush-mounting housing, screw-type terminal (direct connection, ring-type cable lugs)

Region-specific default setting/function and language settings

Region DE, 50 Hz, IEC characteristics, language: German, (language can be selected)

Region World, 50/60 Hz, IEC/ANSI characteristics, language: English (UK), (language can be selected)

Region US, 60 Hz, ANSI characteristics, language: English (US), (language can be selected)

Port B (System interface) No system interface IEC 60870-5-103 protocol, electrical RS232 IEC 60870-5-103 protocol, electrical RS485 IEC 60870-5-103 protocol, optical 820 nm, ST connector Analog output 2 x 0 to 20 mA PROFIBUS DP slave, electrical RS485 PROFIBUS DP slave, optical 820 nm, double ring, ST connector* MODBUS, electrical RS485 MODBUS, optical 820 nm, ST connector* DNP 3.0, electrical RS485 DNP 3.0, optical 820 nm, ST connector* IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connectors IEC 61850, 100 Mbit Ethernet, optical, double, LC connector4) PROFINET I/O, 100 Mbit Ethernet, electrical, double, RJ45-plug PROFINET I/O, 100 Mbit Ethernet, with integrated switch, optical, double, LC connectors3)

L 0A

L 0 B

L 0D

L 0 E

L 0G

L 0H

L 0 R

L 0 S

L 3 R

L 3 S

Only Port C (Service interface) DIGSI 4 /modem, electrical RS232 DIGSI 4 /modem, temperature monitoring box, electrical RS485 Port C (Service interface) and Port D (Additional interface)

Port C (Service interface)

DIGSI 4 /modem, electrical RS232

DIGSI 4 /modem, temperature monitoring box, electrical RS485

Port D (Additional interface) Temperature monitoring box, optical 820 nm, ST connector Temperature monitoring box, electrical RS485 Analog outputs 2 x 0 to 20 mA
1) Rated current can be selected by means of jumpers. 2) Transition between the two auxiliary voltage ranges can be selected
by means of jumpers. 3) The binary input thresholds can be selected in stages by means of
jumpers.

A F K 4) Not available with position 9 = "B" * Not with position 9 = B; if 9 = "B", please order 7UM62 unit with RS485 port and separate fiber-optic converters.

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 11/25

Generator Protection/7UM62
Selection and ordering data

Description

7UM62 multifunction generator, motor and transformer protection relay

Measuring functions

Without extended measuring functions

Min./max. values, energy metering Function

Generator Basic

Generator Standard

Generator Full

Asynchronous Motor

Transformer

Functions (additional functions) Without

Sensitive rotor ground-fault protection and 100 % stator ground-fault protection

Restricted ground-fault protection

Network decoupling (df/dt and vector jump) All additional functions

1) For more detailed information on the functions see Table 11/3.

Order No. 7UM62 - - 0
0 3
A B C F H
A B C E G

Accessories

15
11/26 Siemens SIP · Edition No. 8

Description

Order No.

Connecting cable Cable between PC/notebook (9-pin connector) and protection unit (9-pin connector) (contained in DIGSI 4, but can be ordered additionally) Cable between thermo-box and relay length 5 m/5.5 yd length 25 m/27.3 yd length 50 m/54.7 yd
Coupling device for rotor ground-fault protection
Series resistor for rotor ground-fault protection (group: 013002)
Resistor for underexcitation protection (voltage divider, 20:1) (group: 012009)

7XV5100-4
7XV5103-7AA05 7XV5103-7AA25 7XV5103-7AA50 7XR6100-0CA00
Short code 3PP1336-0DZ K2Y
3PP1326-0BZ K2Y

Resistor for stator ground-fault protection (voltage divider, 5:1) (group 013001)

3PP1336-1CZ K2Y

20 Hz generator 20 Hz band pass filter

7XT3300-0CA00 7XT3400-0CA00

Current transformer (400 A/5 A, 5 VA)

4NC5225-2CE20

Controlling unit f. rotor ground-fault protection (0.5 to 4Hz) 7XT7100-0EA00

Resistor for 1 to 3 Hz rotor ground-fault protection

7XR6004-0CA00

Temperature monitoring box (thermo-box) AC/DC 24 to 60 V AC/DC 90 to 240 V

7XV5662-2AD10 7XV5662-5AD10

LSP2289-afp.eps

Accessories
Fig. 11/27 Mounting rail for 19" rack

LSP2090-afp.eps

LSP2091-afp.eps

Fig. 11/28 2-pin connector

Fig. 11/29 3-pin connector

LSP2092-afp.eps

LSP2093-afp.eps

Fig. 11/30 Short-circuit link for current contacts

Fig. 11/31 Short-circuit link for voltage contacts/ indications contacts

Generator Protection/7UM62
Selection and ordering data

Description

Connector

2-pin 3-pin

Order No.

Size of Supplier Fig.

C73334-A1-C35-1

package

Siemens 11/61

C73334-A1-C36-1 1

Siemens 11/62

Crimp connector

CI2 0.5 to 1 mm2

0-827039-1 0-827396-1

4000

CI2 0.5 to 2.5 mm2

0-827040-1

4000

0-827397-1

Type III+ 0.75 to 1.5 mm2 0-163083-7

4000

Crimping

For type III+

0-163084-2 0-539635-1

tool

and matching female

0-539668-2

For CI2

0-734372-1

and matching female 19"-mounting rail

1-734387-1 C73165-A63-D200-1 1

Siemens 11/60

Short-circuit For current terminals

links

For other terminals

Safety cover large for terminals small

C73334-A1-C33-1 1 C73334-A1-C34-1 1
C73334-A1-C31-1 1 C73334-A1-C32-1 1

Siemens 11/63

Siemens 11/64

Siemens 11/35

1) Your local Siemens representative can inform you on local suppliers.

15
Siemens SIP · Edition No. 8 11/27

Generator Protection/7UM62
Connection diagram, IEC

Fig. 11/32 7UM621 and 7UM623 connection diagram (IEC standard)

11/28 Siemens SIP · Edition No. 8

Generator Protection/7UM62
Connection diagram, IEC

Fig. 11/33 7UM622 connection diagram (IEC standard)

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 11/29

Generator Protection/7UM62
Connection diagram, ANSI

Fig. 11/34 7UM621 and 7UM623 connection diagram (ANSI standard)

11/30 Siemens SIP · Edition No. 8

Generator Protection/7UM62
Connection diagram, ANSI

Fig. 11/35 7UM622 connection diagram (ANSI standard)

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 11/31

Generator Protection/7UM62
Connection diagram, ANSI
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
11/32 Siemens SIP · Edition No. 8

Generator Protection/7VE6
SIPROTEC 7VE6 multifunction paralleling device

Voltage and frequency functions (V>, V<, f>, f< df/dt) including

voltage vector jump () are optionally available for protection or network decoupling applications.

The integrated programmable logic functions (continuous

function chart CFC) offer the user a high flexibility so that

adjustments can easily be made to the varying requirements on the basis of special system conditions.

The flexible communication interfaces are open to modern communication architectures with control systems.
3

Function overview

LSP2483-afpen.tif

Fig. 11/36 SIPROTEC 7VE6 multifunction paralleling device

Basic functions · High reliability with a two-out-of-two design (1½ channels in
7VE61 and 2 channels in 7VE63) · Paralleling of asynchronous voltage sources · Balancing commands for voltage and speed (frequency) · Paralleling of synchronous voltage sources · Synchro-check function for manual synchronization · Parameter blocks for use on several synchronizing points
(7VE61 max. 4 and 7VE63 max. 8)

Description
The 7VE61 and 7VE63 paralleling devices of the SIPROTEC 4 family are multifunctional compact units used for paralleling power systems and generators.
Their technical design ensures highly reliable paralleling due to their 1½-channel or 2-channel measurement method and their hardware design. This is supported by numerous monitoring functions. The units automatically detect the operating conditions. The response to these conditions depends on settings. In "synchronous network switching" mode, the frequency difference is measured with great accuracy. If the frequency difference is almost zero for a long enough time, the networks are already synchronous and a larger making angle is permissible.
If the conditions are asynchronous, as is the case when synchronizing generators, the generator speed is automatically matched to the system frequency and the generator voltage to the system voltage. The connection is then made at the synchronous point, allowing for circuit-breaker make-time.
The 7VE61 paralleling device is a 1½-channel unit (paralleling function + synchro-check) for use with small to medium-size generators and power systems. It is more reliable than 1-channel paralleling devices. It can also be used for synchro-check, with parallel operation of three synchronization points.
For larger generators and power systems with high reliability requirements, the 2-channel 7VE63 is recommended. Two independent methods decide on the connection conditions. The unit also has the full control functions of the SIPROTEC 4 family.

Additional functions · Consideration of transformer vector group and tap changer · Synchronization record (instantaneous or r.m.s. record) · Commissioning support (CB-time measurement, test
synchronization) · Browser operation · Full control functionality of SIPROTEC 4 · Analog outputs of operational measured values · Functions for protection or network decoupling tasks
Protection functions (option) · Undervoltage protection(27) · Overvoltage protection (59) · Frequency protection (81) · Rate-of-frequency-change protection ( 81R) · Jump of voltage vector monitoring
Monitoring functions · Self-supervision of paralleling function · Operational measured values · 8 oscillographic fault records
Communication interfaces · System interface
IEC 60870-5-103 IEC 61850 protocol PROFIBUS DP Modbus RTU and DNP 3 · Service interface for DIGSI 4 (modem) · Front interface for DIGSI 4 · Time synchronization via IRIG B/DCF77

4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 11/33

Generator Protection/7VE6
Application

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Application
The 7VE61 and 7VE63 paralleling devices of the SIPROTEC 4 family are multifunctional compact units used for paralleling power systems and generators.
Their technical design ensures highly reliable paralleling due to their 1½-channel or 2-channel measurement method and their hardware design. This is supported by numerous monitoring functions.
The units automatically detect the operating conditions. The response to these conditions depends on settings.
In "synchronous network switching" mode, the frequency difference is measured with great accuracy. If the frequency difference is almost zero for a long enough time, the networks are already synchronous and a larger making angle is permissible.
If the conditions are asynchronous, as is the case when synchronizing generators, the generator speed is automatically matched to the system frequency and the generator voltage to the system voltage. The connection is then made at the synchronous point, allowing for circuit-breaker make-time.
The 7VE61 paralleling device is a 1½-channel unit (paralleling function + synchro-check) for use with small to medium-size generators and power systems. It is more reliable than 1-channel paralleling devices. It can also be used for synchro-check, with parallel operation of three synchronization points.
For larger generators and power systems with high reliability requirements, the 2-channel 7VE63 is recommended. Two independent methods decide on the connection conditions. The unit also has the full control functions of the SIPROTEC 4 family.
Voltage and frequency functions (V>, V<, f>, f< df/dt) including voltage vector jump () are optionally available for protection or network decoupling applications.
Uniform design
The SIPROTEC 4 units have a uniform design and a degree of functionality which represents a whole new quality in protection and control and automation.
Local operation has been designed according to ergonomic criteria. Large, easy-to-read displays (graphic display for 7VE63) were a major design aim. The DIGSI 4 operating program considerably simplifies planning and engineering and reduces commissioning times.
Highly reliable
The 7VE6 hardware is based on 20 years of Siemens experience with numerical protection equipment. State-of-the-art technology and a high-efficiency, 32-bit microprocessor are employed. Production is subject to exacting quality standards.
Special attention has been paid to electromagnetic compatibility, and the number of electronic modules has been drastically reduced by the use of highly integrated circuits.
The software design incorporates accumulated experience and the latest technical knowledge. Object orientation and high-level language programming, combined with the continuous quality assurance system, ensure maximized software reliability.

Programmable logic
The integrated programmable logic function allows the user to implement his own functions for automation of switchgear (interlocking) via a graphic user interface. The user can also generate user-defined messages.
Adjustments can easily be made to the varying power station requirements.
Measurement method
Powerful and successful algorithms based on years of experience have been incorporated. They ensure both a high level of measurement accuracy and effective noise signal suppression. That makes for reliable paralleling even in networks with harmonics. Complementary measurement methods avoid unwanted operation.
Design
The units are available in two designs: the ½ 19" wide 7VE61 and the ½ 19" wide 7VE63. The 7VE61 features a four-line display. The 7VE63 is equipped with a graphic display for visualization of switching states. It also has a larger number of binary inputs and outputs than the 7VE61.
Communication
Flexible and powerful communication is paramount. That is why the paralleling devices have up to five serial interfaces (for details see chapter 4 "Communication"): Front interface for connecting a PC Service interface for connecting a PC (e.g. via a modem) System interface for connecting to a control system via
IEC 60870-5-103, IEC 61850, PROFIBUS DP, MODBUS RTU or DNP 3.0 Interface for an analog output module (2 20 mA) and an input For time synchronization via DCF77 or IRIG B.
Operational measured values
In order to assist system management and for commissioning purposes, relevant measured values are displayed as primary and secondary values with unit and values relating to the object to be protected.
The measured values can also be transferred via the serial interfaces.
In addition, the programmable logic permits limit value scans and status indications derived therefrom.
Metered values are available in the form of energy metered values for the active and reactive energy supplied and are also provided by an elapsed-hour meter.

11/34 Siemens SIP · Edition No. 8

Generator Protection/7VE6
Application, functions

Indications
The SIPROTEC 4 units provide detailed data for analysis of synchronization (fault events from activated protection functions) and for checking states during operation. All indications are protected against power supply failure.
· Synchronization indications (Fault indications) The last eight synchronizations (faults) are stored in the unit at all times. A fresh synchronization (fault) will erase the oldest one. The fault indications have a time resolution of 1 ms. They provide detailed information on history. The buffer memory is designed for a total of 600 indications.
· Operational indications All indications that are not directly associated with the synchronization (fault) (e.g. operating or switching actions) are stored in the status indication buffer. The time resolution is 1 ms, buffer size: 200 indications.
Fault recording at up to 10 or 100 seconds
An instantaneous value or r.m.s. value recorder is provided. The firmware permits storage of 8 fault recordings. Triggering can be effected by the synchronization function (starting or closing command), protection function (pickup or tripping), binary input, the DIGSI 4 operating program or by the control system.
The instantaneous value recording stores the voltage input values (va, vb, vc, vd, ve, vf), voltage differences (va-vd, vb-ve, vc-vf), and calculated r.m.s. values V, f, at 1-ms intervals (or 0.83-ms intervals for 60 Hz). The r.m.s. values are calculated every half cycle. The total duration of the fault recording is 10 seconds. If the time is exceeded, the oldest recording is overwritten.
If you want to record for a longer period for commissioning purposes (for example, to show the effect of balancing commands), r.m.s. value recording is advisable. The relevant calculated values (V1,V2, f1, f2, V, f, ) are recorded at half-cycle intervals. The total duration is 100 seconds.
Time synchronization
A battery-backed clock is a standard component and can be synchronized via a synchronization signal (DCF77; IRIG B via satellite receiver), binary input, system interface or SCADA (e.g. SICAM). A date and time are assigned to every indication.
Freely assignable binary inputs and outputs
Binary inputs, output relays, and LEDs can each be given separate user-specific assignments. Assignment is effected using a software matrix, which greatly simplifies the allocation of individual signals.
To ensure dual-channel redundancy, control of the CLOSE relay (relay R1 and R2) is prioritized and should not be altered. These two relays have a special, highly reliable control and monitoring logic (see Fig. 11/89).

Continuous self-monitoring
The hardware and software are continuously monitored. If abnormal conditions are detected, the unit signals immediately. In this way, a great degree of safety, reliability and availability is achieved.
Reliable battery monitoring
The battery buffers the indications and fault recordings in the event of power supply voltage failure. Its function is checked at regular intervals by the processor. If the capacity of the battery is found to be declining, an alarm indication is generated.
All setting parameters are stored in the Flash-EPROM which are not lost if the power supply or battery fails. The SIPROTEC 4 unit remains fully functional.
Functions
Functional scope of the paralleling function
The units contain numerous individually settable functions for different applications. They cover the following operating modes:
Synchro-check
In this mode, the variables V, f, are checked. If they reach set values, a release command is issued for as long as all three conditions are met, but at least for a settable time.
Switching synchronous networks
The characteristic of synchronous networks is their identical frequency (f0). This state is detected, and fulfillment of the V and conditions is checked. If the conditions remain met for a set time, the CLOSE command is issued.
Switching asynchronous networks
This state occurs in the power system and generator (open generator circuit-breaker). A check is made for fulfillment of V and f conditions and the connection time is calculated, taking account of , and the circuit-breaker making time. By means of balancing commands (for voltage and frequency), the generator can automatically be put into a synchronous condition.
Switching onto dead busbars
The voltage inputs are checked here. The CLOSE command is issued depending on the set program and the result of measurement. A three-phase connection increases reliability because several voltages must fulfill the conditions (see Fig. 11/84).
The following operating states are possible: V1< V2 >
(connection to dead busbar (side 1)) V1> V2 <
(connection to dead line (side 2)) V1< V2 <
(forced closing)

1 2 3 4 5 6 7 8 9 10 11 12 13 14

15
Siemens SIP · Edition No. 8 11/35

Generator Protection/7VE6
Functions

1 2 3 4 5 6 7 8 9 10 11 12 13

Voltage and frequency band query
Synchronization is not activated until the set limits are reached. Then the remaining parameters (see above) are checked.

Vector group adaptation
If synchronization is effected using a transformer, the unit will take account of the phase-angle rotation of the voltage phasor in accordance with the vector group entry for the transformer. On transformers with a tap changer, the tap setting can be communicated to the unit, for example, as BCD code (implemented in the 7VE63). When using the IEC 61850 communication standard, it is possible to detect tap position indications with a bay control unit (e.g. 6MD66) and to transmit these indications via GOOSE to the 7VE6 paralleling device. Deviations from the rated transformation ratio result in the appropriate voltage amplitude adaptation.

Fig. 11/37 SIGRA 4, synchronization record with balancing commands

LSP2480fen.tif

Voltage and frequency balancing
If the synchronization conditions are not fulfilled, the unit will automatically issue balancing signals. These are the appropriate up or down commands to the voltage or speed controller (frequency controller). The balancing signals are proportional to the voltage or frequency difference, which means that if the voltage or frequency difference is substantial, longer balancing commands will be output. A set pause is allowed to elapse between balancing commands to allow the state change to settle. This method ensures rapid balancing of the generator voltage or frequency to the target conditions.
If identical frequency is detected during generator-network synchronization ("motionless synchronization phasor"), a kick pulse will put the generator out of this state.
For example, if the voltage is to be adjusted using the transformer tap changer, a defined control pulse will be issued.
Several synchronizing points
Depending on the ordered scope, several synchronization points can be operated. The data for synchronization of each circuit-breaker (synchronization function group) are stored individually. In the maximum version, the 7VE63 operates up to 8 synchronization points. Selection is made either via the binary input or the serial interface. With the CFC, it is also possible to control the connection of the measured variables or commands via a master relay.

Commissioning aids
The paralleling device is designed to be commissioned without an external tester/recorder (see Fig. 11/84). For that purpose, it contains a codeword-protected commissioning section. This can be used to measure the make time automatically with the unit (internal command issue until the CB poles are closed). This process is logged by the fault recording function.
The operational measured values also include all measured values required for commissioning. The behavior of the paralleling function or the unit is also documented in detail in the operational annunciation and synchronization annunciation buffer. The connection conditions are documented in the synchronization record. Test synchronization is also permitted. All actions inside the synchronizer are taken but the two CLOSE relays are not operated (R1 and R2). This state can also be initiated via a binary input.

15
11/36 Siemens SIP · Edition No. 8

Generator Protection/7VE6
Functions

5
Fig. 11/38 Two-channel redundancy

Great safety and reliability due to multi-channel redundancy
Generator synchronization especially requires units in which unwanted operation can be ruled out. The paralleling device achieves this multi-channel redundancy with a two-out-of-two decision. That means that two conditions for the CLOSE command must be fulfilled. Fig. 11/85 shows the structure of the two designs.
In the 1½-channel version (7VE61), the paralleling function is the function that gives the CLOSE command. The synchro-check function acts as a release criterion with rougher monitoring limit settings. Other monitoring functions are also active at the same time (see below).
In the two-channel version (7VE63), two independent methods work in parallel. The CLOSE command is given when the two methods simultaneously decide on CLOSE. Fig. 11/86 shows the consistent implementation of dual-channel redundancy.
The measured quantities are fed to two ADCs. The second ADC processes the values rotated through 180° (e.g. V1). The monitoring methods test all the transformer circuits including internal data acquisition for plausibility and they block measurement if deviations are found. The phase-sequence test detects connection errors. The measuring methods 1 and 2 include the measurement algorithms and logic functions.
In keeping with the two-channel redundancy principle, differing measurement methods are used to prevent unwanted operation due to systematic errors.
In addition, numerous methods are also active, such as closure monitoring (synchronism monitoring of both methods). Unwanted relay operation is avoided by two-channel operation of both CLOSE relays. The two measurement methods operate the transistors crossed over.

1 ½-channel version (7VE61)
2-channel version (7VE63)
Fig. 11/39 Design of multi-channel redundancy
Moreover, coil operation is monitored in the background. For this purpose, transistors are activated individually and the response is fed back. Both interruptions and transistor breakdown are detected. When faults are found, the unit is blocked immediately. The plausibility monitoring of set values (valid limits) and selection of the synchronization function groups (only one can be selected) are also supported. In the event of any deviations, messages are output and the paralleling function is blocked.

6 7 8 9 10 11 12 13 14

15
Siemens SIP · Edition No. 8 11/37

Generator Protection/7VE6
Functions

Internet technology simplifies

commissioning In addition to the universal DIGSI 4 oper-

ating program, the synchronizer contains

a Web server that can be accessed via a

telecommunications link using a browser (e.g. Internet Explorer). The advantage of

this solution is that it is both possible to

operate the unit with standard software

tools and to make use of the Intranet/

Internet infrastructure. Moreover, infor-

mation can be stored in the unit without

any problems. In addition to numeric

values, visualizations facilitate work with

the unit. In particular, graphical displays provide clear information and a high

degree of operating reliability. Fig. 11/88

shows an example of an overview that is

familiar from conventional synchronizers. The current status of synchronization

Fig. 11/40 Browser-based operation

conditions is clearly visible. Of course, it

is possible to call up further measured

value displays and annunciation buffers.

By emulation of integrated unit opera-

tion, it is also possible to adjust selected

settings for commissioning purposes,

(see Fig. 11/87).

LSP2481fen.tif

LSP2482fen.tif

10 11

Fig. 11/41 Overview display of the synchronization function

15
11/38 Siemens SIP · Edition No. 8

Generator Protection/7VE6
Functions

Protection and automation functions
Basic concept
The paralleling function is not performed constantly. Therefore the measured quantities provided at the analog inputs are available for other functions. Voltage and frequency protection or limit value monitoring of these quantities are typical applications. Another possible application is network decoupling. After network disconnection, automatic resynchronization using the CFC is possible on request. To allow for great flexibility, these functions can be assigned to the analog inputs. This is defined for the specific application.
Undervoltage protection (ANSI 27)
The protection function is implemented on two stages and evaluates the voltage at an input assigned to it. Analysis of a phase-to-phase voltage is beneficial as it avoids starting in the event of ground faults. The protection function can be used for monitoring and decoupling purposes or to prevent voltageinduced instability of generators by disconnection.
Overvoltage protection (ANSI 59)
The protection function is implemented on two stages and evaluates the voltage at an input assigned to it. The overvoltage protection prevents impermissible stress on equipment due to excessive voltages.
Frequency protection (ANSI 81)
The protection function is implemented on four stages and evaluates the frequency of an input assigned to it. Depending on the frequency threshold setting, the function can provide overfrequency protection (setting > fn) or underfrequency protection (setting < fn). Each stage can be delayed separately. Stage 4 can be configured either as an overfrequency or underfrequency stage.
The application consists of frequency monitoring usually causing network disconnection in the event of any deviations. The function is suitable as a load shedding criterion.

Jump of voltage vector monitoring
Smaller generating plants frequently require the vector jump function. With this criterion it is possible to detect a disconnected supply (e.g. due to the dead time during an automatic reclosure) and initiate generator disconnection. This avoids impermissible loads on the generating plant, especially the drive gearing, if reconnection to the network is asynchronous.
The vector jump function monitors the phase angle change in the voltage.
If the incoming line should fail, the abrupt current discontinuity leads to a phase angle jump in the voltage. This is measured by means of a delta process. The command for opening the generator or coupler circuit- breaker is issued if the set threshold is exceeded.
Vector jump monitoring is performed again for the assigned voltage input. This function is blocked during synchronization.
Threshold monitoring
The threshold function is provided for fast monitoring and further processing in the CFC. Optional monitoring of the calculated voltage (for violation of an upper or lower threshold) at the six voltage inputs is possible. A total of three greater-than and three less-than thresholds are available. The check is made once per cycle, resulting in a minimum operating time of about 30 ms for the voltage. The times can be extended by the internal check time, if necessary (about 1 cycle).

Rate-of-frequency-change protection (ANSI 81R)
This function can also be assigned to an input. The frequency difference is determined on the basis of the calculated frequency over a time interval. It corresponds to the momentary rate-offrequency change. The function is designed to react to both positive and negative rate-of-frequency changes. Exceeding of the permissible rate-of-frequency change is monitored constantly. Release of the relevant direction depends on whether the actual frequency is above or below the rated frequency. In total, four stages are available, and can be used optionally.
This function is used for fast load shedding or for network decoupling.

1 2 3 4 5 6 7 8 9 10 11 12 13

15
Siemens SIP · Edition No. 8 11/39

Generator Protection/7VE6
Typical applications

Typical applications

Connection to three-phase voltage

transformer

If three-phase voltage transformers are

available, connection as shown in Fig. 11/89 is recommended. This is the

standard circuit because it provides a

high level of reliability for the paralleling

function. The phase-sequence test is additionally active, and several voltages are

checked on connection to a dead busbar.

Interruption in the voltage connection does

not lead to unwanted operation. Please note that side 1 (that is, V1) is always the

feed side. That is important for thedirection

of balancing commands.

7 8 9 10 11

Connection to open delta connection (V-connection) voltage transformer
Fig. 11/90 shows an alternative to Fig. 11/89 for substations in which the voltage transformers have to be V-connected. For the paralleling device, this connection is the electrical equivalent of the connection described above. It is also possible to combine the two: three one-pole isolated voltage transformers on one side and the V-connection on the other. If, additionally, a synchroscope is connected, it must be electrically isolated by means of an interposing transformer.

Fig. 11/42

Fig. 11/43

15
11/40 Siemens SIP · Edition No. 8

Connection to floating voltage transformer
To save costs for the voltage transformer, two-phase isolated voltage transformers are used that are connected to the phaseto-phase voltage (see Fig. 11/91). In that case, the phase-rotation supervision is inactive and reliability restrictions when connecting to the dead busbarmust be accepted.
Full two-channel redundancy is ensured.

Generator Protection/7VE6
Typical applications
1 2 3 4

Fig. 11/44
Connection to single-phase isolated voltage transformer
As an alternative to Fig. 11/91, some substations use single-phase isolated voltage transformers (see Fig. 11/92). In this case, only a phase-to-ground voltage is available. This connection should be avoided if possible. Especially in isolated or resonant-(star point) neutral-grounded networks, an ground fault would lead to a voltage value of zero. That does not permit synchronization and the busbar is detected as dead.
If V1< and V2 > connection is permitted, there is a high risk of incorrect synchronization. Furthermore, an ground fault in phase L2 leads to an angle rotation of for instance 30° in phase L1. This means that the device switches at a large fault angle.

6 7 8 9 10 11 12

Fig. 11/45

15
Siemens SIP · Edition No. 8 11/41

Generator Protection/7VE6
Typical applications

Switching in 16.7 Hz networks for

application in traction systems The unit can also be used for synchronizing

railway networks or generators. The

connection has to be executed according

to Fig. 11/93. No phase sequence test is available here. Two-channel redundancy is

ensured.

The voltage inputs permit the application

of the 16.7 Hz frequency without any difficulties.

On connection to a dead busbar, a broken

wire in the external voltage transformer

circuit is not detected. It is recommended to make another interrogation of a second

voltage transformer.

6
Fig. 11/46
7

15
11/42 Siemens SIP · Edition No. 8

Generator Protection/7VE6
Typical applications

Synchro-check for several synchroniz-

ing points To avoid unwanted operation during

manual synchronization or during con-

nection of circuit-breakers in the network,

the synchro-check function is used as an enabling criterion. It is fully compatible

with all of the connections described

above (see Figs. 11/89 to 11/93). With

the "synchro-check" ordering option, the

paralleling device also allows up to three

circuit-breakers to bemonitored in parallel.

That saves wiring, switching and testing.

In particular, that is an application for the

1½ circuit-breaker method. Moreover, on smaller generating plants one unit can

be used for up to three generators, which

helps reduce costs.

The connection shown in Fig. 11/94 is a single-pole version, which is acceptable for

the synchro-check function.

An alternative is the connection for two switching devices (see Fig. 11/95).

The two free voltage inputs can be used for monitoring purposes.

Fig. 11/47

Fig. 11/48

13 14

15
Siemens SIP · Edition No. 8 11/43

Generator Protection/7VE6
Typical applications

Fig. 11/49

DIGSI: BI "L" active

10 11 12 13

Synchronization of a generator
Fig. 11/96 shows an example of the 7VE61 paralleling device connected to a medium-power generator.Where three-phase voltage transformers are available, direct connection is recommended. The synchronization point and start of synchronization is selected via the binary inputs. If cancellation is necessary, the stop input must be used.
If synchronization onto a dead busbar is permitted, the alarm contact of the voltage transformer miniature circuit-breakers (m.c.b.) must be connected to the unit.
Relays R1 and R2 are used for a CLOSE command. The other relays are used for selected indications and for the balancing commands.
The live status contact operated by the unit self-supervision function must also be wired.

15
11/44 Siemens SIP · Edition No. 8

Generator Protection/7VE6
Technical data

General unit data Analog inputs Rated frequency Rated voltage VN Power consumption
Voltage inputs (at 100 V) Capability in voltage paths Auxiliary voltage Rated auxiliary voltage
Permitted tolerance Superimposed AC voltage (peak-to-peak) Power consumption
Quiescent 7VE61 7VE63 Energized 7VE61 7VE63 Bridging time during auxiliary voltage failure at Vaux = 48 V and Vaux 110 V at Vaux = 24 V and Vaux = 60 V Binary inputs Quantity 7VE61 7VE63 3 pickup thresholds Range is settable with jumpers Maximum permissible voltage Current consumption, energized Output relays Quantity 7VE61
7VE62
7VE61+7VE63
Switching capacity Make Break Break (for resistive load) Break (for L/R 50 ms)
Switching voltage Permissible current
LEDs Quantity
RUN (green) ERROR (red) Assignable LED (red)
7VE61 7VE63

50, 60 or 16.7 Hz 100 to 125 V
Approx. 0.3 VA 230 V continuous
DC 24 to 48 V DC 60 to 125 V DC 110 to 250 V DC 220 to 250 V AC 115 and 230 V (50/60 Hz) -20 to +20 % 15 %
Approx. 4 W Approx. 5.5 W
Approx. 9.5 W Approx. 12 W
50 ms 20 ms
6 14 DC 14 to 19 V, DC 66 to 88 V; DC 117 to 176 V DC 300 V Approx. 1.8 mA
9 (each with 1 NO; 1 optional as NC, via jumper) 17 (each with 1 NO; 2 optional as NC, via jumper) 1 live status contact (NC, NO via jumper)
1000 W / VA 30 VA 40 W 25 W 250 V 5 A continuous 30 A for 0.5 seconds
1 1
7 14

Unit design

7XP20 housing

For dimensions see dimension drawings part 14

Degree of protection acc. to

EN 60529

For surface-mounting housing IP 51

For flush-mounting housing Front

IP 51

Rear

IP 50

For the terminals

IP 2x with terminal cover put on

Weight Flush-mounting housing 7VE61 (½ x 19")

Approx. 5.2 kg

7VE63 (½ x 19")

Approx. 7 kg

Surface-mounting housing

7VE61 (½ x 19") 7VE63 (½ x 19")

Approx. 9.2 kg Approx. 12

Electrical tests

Specifications

Standards

IEC 60255 (product standards) ANSI/IEEE C37.90.0/.1/.2 UL 508 DIN 57435, part 303 For further standards see below

Insulating tests

Standards

IEC 60255-5

Voltage test (100 % test)

2.5 kV (r.m.s.), 50/60 Hz

All circuits except for auxiliary sup-

ply, binary inputs, communication

and time synchronization interfaces

Voltage test (100 % test)

DC 3.5 kV

Auxiliary voltage and binary inputs

Voltage test (100 % test) only

500 V (r.m.s. value), 50/60 Hz

isolated communication interfaces

and time synchronization interface

Impulse voltage test (type test) 5 kV (peak); 1.2/50 s; 0.5 J; All circuits except for communica- 3 positive and 3 negative impulses tion interfaces and time synchroni- at intervals of 5 s zation interface, class III

EMC tests for noise immunity (type test)

Standards

IEC 60255-6, IEC 60255-22 (product standards) EN 50082-2 (generic standard) DIN 57435 part 303

High frequency test IEC 60255-22-1, class III and DIN 57435 part 303, class III

2.5 kV (peak value), 1 MHz; = 15 ms 400 pulses per s; duration 2 s

Electrostatic discharge IEC 60255-22-2, class IV EN 61000-4-2, class IV
Irradiation with RF field, non-modulated IEC 60255-22-3 (report), class III

8 kV contact discharge; 15 kV air discharge; both polarities; 150 pF; Ri = 330
10 V/m; 27 to 500 MHz

Irradiation with RF field, amplitude-modulated, IEC 61000-4-3, class III

10 V/m; 80 to 1000 MHz; 80 % AM; 1 kHz

5 6 7 8 9 10 11 12 13

15
Siemens SIP · Edition No. 8 11/45

Generator Protection/7VE6
Technical data

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Irradiation with RF field,

10 V/m; 900 MHz; repetition

pulse-modulated

frequency 200 Hz; duty cycle 50 %

IEC 61000-4-3/ ENV 50204, class III

Fast transient interference bursts IEC 60255-22-4, IEC 61000-4-4, class IV

4 kV; 5/50 ns; 5 kHz; burst length = 15 ms; repetition rate 300 ms; both polarities; Ri = 50 ; test duration 1 min

High-energy surge voltages (SURGE), IEC 61000-4-5 installation, class III Auxiliary supply

Impulse: 1.2/50 s
Common (longitudinal) mode: 2 kV; 12 , 9 F Differential (transversal) mode: 1 kV; 2 , 18 F

Measurement inputs, binary inputs

and relay outputs

Common (longitudinal) mode:

2 kV; 42 , 0.5 F

Differential (transversal) mode:

1 kV; 42 , 0.5 F

Line-conducted HF, amplitude-modulated IEC 61000-4-6, class III

10 V; 150 kHz to 80 MHz; 80 % AM; 1 kHz

Magnetic field with power frequency 30 A/m continuous; IEC 61000-4-8, class IV; IEC 60255-6 300 A/m for 3 s; 50 Hz
0.5 mT; 50 Hz

Oscillatory surge withstand capability ANSI/IEEE C37.90.1
Fast transient surge withstand capability ANSI/IEEE C37.90.1
Radiated electromagnetic interference ANSI/IEEE C37.90.2

2.5 to 3 kV (peak); 1 to 1.5 MHz damped wave; 50 surges per second; Duration 2 s; Ri = 150 to 200
4 to 5 kV; 10/150 ns; 50 surges per second; both polarities; duration 2 s ; Ri = 80
35 V/m; 25 to 1000 MHz

Damped oscillations IEC 60894, IEC 61000-4-12

2.5 kV (peak value), polarity alternating 100 kHz, 1 MHz, 10 and 50 MHz, Ri = 200

EMC tests for interference emission (type test)

Standard

EN 50081-x (generic standard)

Conducted interference voltage on lines only auxiliary supply IEC-CISPR 22

150 kHz to 30 MHz Limit class B

Interference field strength IEC-CISPR 22

30 to 1000 MHz Limit class B

Mechanical stress tests

Vibration, shock stress and seismic vibration

During operation

Standards

EC 60255-21 and IEC 60068

Vibration IEC 60255-21-1, class II IEC 60068-2-6

Sinusoidal 10 to 60 Hz: ± 0.075 mm amplitude; 60 to 150 Hz: 1 g acceleration Frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes

Shock IEC 60255-21-2, class I IEC 60068-2-27

Half-sinusoidal Acceleration 5 g, duration 11 ms, 3 shocks each in both directions of the 3 axes

Seismic vibration IEC 60255-21-2, class I IEC 60068-3-3
During transport Standards Vibration IEC 60255-21-1, class II IEC 60068-2-6
Shock IEC 60255-21-2, class I IEC 60068-2-27
Continuous shock IEC 60255-21-2, class I IEC 60068-2-29

Sinusoidal 1 to 8 Hz: ± 3.5 mm amplitude (horizontal axis) 1 to 8 Hz: ± 1.5 mm amplitude (vertical axis) 8 to 35 Hz: 1 g acceleration (horizontal axis) 8 to 35 Hz: 0.5 g acceleration (vertical axis) Frequency sweep 1 octave/min 1 cycle in 3 orthogonal axes
IEC 60255-21 and IEC 60068-2
Sinusoidal 5 to 8 Hz: ±7.5 mm amplitude; 8 to 150 Hz: 2 g acceleration Frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes
Half-sinusoidal Acceleration 15 g, duration 11 ms, 3 shocks each in both directions 3 axes
Half-sinusoidal Acceleration 10 g, duration 16 ms, 1000 shocks in both directions of the 3 axes

Climatic stress test Temperatures
Standards Recommended operating limiting temperature Temporarily permissible operating temperature
Limiting temperature during permanent storage (with supplied packing) Limiting temperature during transport (with supplied packing)
Humidity
Standards Permissible humidity stress It is recommended to arrange the units in such a way that they are not exposed to direct sunlight or pronounced temperature changes that could cause condensation

IEC 60068-2-1, IEC 60068-2-2 5 °C to +55 °C / +25 °F to +131 °F
-20 to +70 °C (Legibility of display may be impaired above +55 °C / +131 °F) 25 °C to +55 °C / 13 °F to +131 °F
25 °C to +70 °C / 13 °F to +158 °F
IEC 60068-2-3 Annual average 75 % relative humidity; on 56 days a year up to 93 % relative humidity; condensation is not permit

15
11/46 Siemens SIP · Edition No. 8

Futher information can be found in the current manual at: www.siemens.com/siprotec

Generator Protection/7VE6
Selection and ordering data

Description 7VE61multifunction paralleling unit Housing 19", 6 BI, 9 BO, 1 live status contact
Auxiliary voltage (power supply, indication voltage) 24 to 48 V DC , threshold binary input 19 V 60 to 125 V DC, threshold binary input 19 V 110 to 250 V DC, 115 to 230 V AC, threshold binary input 88 V DC 220 to 250 V DC, 115 to 230 V AC, threshold binary input 176 V DC
Unit design Surface-mounting housing, 2-tier screw-type terminals at top/bottom Flush-mounting housing, screw-type terminals (direct connection/ring-type cable lugs)
Region-specific default setting/function and language settings Region DE, 50 Hz, language German (language selectable) Region World, 50/60 Hz, language English (GB) (language selectable) Region US, 60 Hz, language English (US) (language selectable) Region World, 50/60 Hz, language Spanish (language selectable)
Port B (system interface) No system interface IEC 60870-5-103-protocol, electrical RS232 IEC 60870-5-103-protocol, electrical RS485 IEC 60870-5-103-protocol, optical 820 nm, ST connector Analog outputs 2 x 0 to 20 mA or 4 to 20 mA PROFIBUS DP Slave, electrical RS485 PROFIBUS DP Slave, optical 820 nm, double ring, ST connector1) MODBUS RTU, electrical RS485 MODBUS RTU, optical 820 nm, ST connector1) DNP 3.0, electrical RS485 DNP 3.0, optical 820 nm, ST connector1) IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connectors IEC 61850, 100 Mbit Ethernet, optical, double, LC connector2)
Port C (service interface) DIGSI 4/modem, electrical RS232 DIGSI 4/modem, electrical RS485
Port C (service interface) and Port D (additional interface) Port C (service interface) DIGSI 4/modem, electrical RS232 DIGSI 4/modem, electrical RS485
Port D (additional interface) Analog outputs 2 x 0 to 20 mA or 4 to 20 mA
Scope of functions of the unit Synchro-check for up to 3 synchronizing points (with dead bus/line monitoring) Paralleling function for 2 synchronizing points without balancing commands, 1½-channel, synchro-check in 2nd channel Paralleling function for 2 synchronizing points with balancing commands, 1½-channel, synchro-check in 2nd channel Paralleling function for 4 synchronizing points with balancing commands, 1½-channel, synchro-check in 2nd channel
Additional functions Without A Protection and network decoupling function (voltage, frequency and rate-of-frequency-change protection, vector jump)
Additional applications Without Application for traction systems (fn = 16.7Hz)

Order No.

Order code

7VE6110- -0 -

2 4 5 6
B E
A B C E
0 1 2 3 7 9 9 9 9 9 9 9 9
1 2

L 0A L 0 B L 0D L 0 E L 0G L 0H L 0 R L 0 S

M 1

M 2

A B C D

A B

0 1

1) With position 9 = B (surface-mounting housing) the unit must be ordered with RS485 interface and a separate FO converter.

2) Not available with position 9 = "B"

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 11/47

Generator Protection/7VE6
Selection and ordering data

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Description 7VE613multifunction paralleling unit HHoouussiinngg½ 1199"",,61B4I,B9I, B1O7 ,B1Ol,i1velivsetasttuastucos nctoancttact
Auxiliary voltage (power supply, indication voltage) DC 24 to 48 V, hthreresshhooldldbbininaarryyininppuutt1199VV DC 60 to 125 V, threshold binary input 19 V DC 110 to 250 V, AC 115 to 230 V, threshold binary input 8D8C V88 V 2D2C02t2o02t5o02V50DVC, A1C1511to52to3023V0AVC,, tthhrreesshhoolldd bbiinnaarryy iinnppuutt D1C7617V6DVC
Unit design Surface-mounting housing, 2-tier screw-type terminals at top/bottom Flush-mounting housing, screw-type terminals (direct connection/ring-type cable lugs)
Region-specific default setting//ffuunnccttiioonnaannddllaanngguuaaggeesseettttiinnggss Region DE, 50HHzz,,lalanngguuaaggeeGGeerrmmaann((llaanngguuaaggeesseelleeccttaabbllee)) Region World, 50/60 Hz, language English (GB) (language selectable) Region US, 60HHzz,,lalanngguuaaggeeEEnngglliisshh((UUSS))((llaanngguuaaggeesseelleeccttaabbllee)) Region World, 50/60 Hz, language Spanish (language selectable)
Port B (systemiinntteerrffaaccee)) No system interface IEC 60870-5-103-protocol, electrical RS232 IEC 60870-5-103-protocol, electrical RS485 IEC 60870-5-103-protocol, optical 820 nm, ST connector Analog outputs 2 x 0 to 20 mA or 4 to 20 mA PROFIBUS DP Slave, electrical RS485 PROFIBUS DP Slave, optical 820 nm, double ring, ST connector1) MODBUS RTU, electrical RS485 MODBUS RTU, optical 820 nm, ST connector1) DNP 3.0, electrical RS485 DNP 3.0, optical 820 nm, ST connector1) IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connectors IEC 61850, 100 Mbit Ethernet, optical, double, LC connector2)
Port C (service interface) DIGSI 4/modem, electrical RS232 DIGSI 4/modem, electrical RS485
Port C (service interface) and Port D((additional interface) Port C (service interface) DIGSI 4//mmooddeemm,,eeleleccttrricicaallRRSS223322 DIGSI 4//mmooddeemm,,eeleleccttrricicaallRRSS448855
Port D (additional interface) Analog outputs 2 x 0 to 20 mA or 4 to 20 mA
Scope of functions of the unit Synchro-check for up to 3 synchronizing points (with dead bus//lilnineemmoonnitiotorirningg) ) Paralleling function for 2 synchronizing points without balancing commands, 12½-c-hcahnannenle, l, sinydnecpheron-dcehnetckmiena2snudricnhgapnrnoecledures Paralleling function for 2 synchronizing points with balancing commands, 21-½c-hcahnannenle, l, isnydnecpheron-dcehnetckmiena2snudricnhgapnrnoecledures Paralleling function for 84 synchronizing points with balancing commands, 21-½c-hcahnannenle, l, isnydnecpheron-dcehnetckmiena2snudricnhgapnrnoecledures
Additional functions Without A Protection and network decoupling function (voltage, frequency and rate-of-frequency-change protection, vector jump)
Additional applications Without Application for traction systems (fn = 16.7Hz)

Order No.

Order code

7VE631210- -0 -

2 4 5 6
B E
A B C E
0 1 2 3 7 9 9 9 9 9 9 9 9
1 2

L 0A L 0 B L 0D L 0 E L 0G L 0H L 0 R L 0 S

M 1

M 2

A B C D

A B

0 1

1) With position 9 = B (surface-mounting housing) the unit must be ordered with RS485 interface and a separate FO converter.

2) Not available with position 9 = "B"

11/48 Siemens SIP · Edition No. 8

LSP2092-afp.eps LSP2289-afp.eps

Accessories
Accessories Fig. 11/50 Short-circuit link
for voltage contacts Fig. 11/51 Mounting rail for 19" rack

Generator Protection/7VE6
Selection and ordering data

Description
Copper connecting cable Cable between PC/notebook (9-pin connector) and protection unit (9-pin connector) (contained in DIGSI 4, but can be ordered additionally)
Manual 7VE61 and 7VE63 Multifunction Paralleling Device

Order No.
1
7XV5100-4
2
C53000-G1176-C163-1

Description

Order No.

3
Size of Supplier package

Crimp connector

CI2 0.5 to 1 mm2

0-827039-1 0-827396-1

4000

CI2 0.5 to 2.5 mm2

0-827040-1 0-827397-1

4000

Type III+ 0.75 to 1.5 mm2

0-163083-7 0-163084-2

4000

0-539635-1

Crimping

For type III+

0-539668-2

tool

and matching female 0-734372-1

For CI2 and matching female

1-734387-1

19"-mounting rail

C73165-A63-D200-1 1

Siemens

Short-circuit links For voltage terminals C73334-A1-C34-1 1

Safety cover

large

C73334-A1-C31-1 1

Siemens Siemens

for terminals

small

C73334-A1-C32-1 1

Siemens

1) Your local Siemens representative can inform you on local suppliers.
8

15
Siemens SIP · Edition No. 8 11/49

Generator Protection/7VE6
Connection diagram

Fig. 11/52 Connection diagram

11/50 Siemens SIP · Edition No. 8

Fig. 11/53 Connection diagram

Generator Protection/7VE6
Connection diagram
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Siemens SIP · Edition No. 8 11/51

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
11/52 Siemens SIP · Edition No. 8

Generator Protection/7VU683
High Speed Busbar Transfer

Function overview

Fig. 11/54 S IPROTEC 7VU683 high speed busbar transfer device
Description
Permanent availability of electricity is essential for reliable production of a great number of processes in power stations and industrial plants where lots of inductive motor are installed. To achieve this, a busbar is normally equipped with two or more independent in-coming power sources to provide the possibility to switch to standby source in case of main source interruption or failure.
The power supply interruption with tens of millisecond has small impact to rotating loads. Thus, the High Speed Busbar Transfer (HSBT) device helps to control and monitor the progress to ensure the fast but reliable switching-over. It can be initiated manually or automatically.
Based on the existing world-wide used SIPROTEC 4 platform, the reliability, stability and efficiency of HSBT 7VU683 are guaranteed. Thanks to its powerful and flexible performance, multi functions are integrated into one system, e.g, power supply transfer, relay protection and supervision.
The compact solution HSBT 7VU683 is designed to fit for the primary diagrams of single busbar (2 CBs) and segmented single busbar (3 CBs). It has incorporated the traditional HSBT philosophy. Additionally, the unique Real Time Fast Transfer mode helps to improve the efficiency.
The integrated protective functions are to protect the tie-CB in segmented single busbar diagram against short-circuit and ground fault. The integrated supervision functions are to monitor the voltage phase sequence and voltage secondary circuit , then gives out alarm in case of failure.
The integrated programmable logic (CFC) allows the users to implement their own functions. The flexible communication interfaces are open for modern communication architectures with control system.

LSP2187-afp.tif

High speed busbar transfer function · Starting conditions
- NORMAL condition - FAULT condition - Inadmissible under-voltage - Inadmissible under-frequency - Inadvertent CB open · Switching sequences - PARALLEL Auto switching sequence - PARALLEL Half-Auto switching sequence - SIMULTANEOUS switching sequence - SEQUENTIAL sequence · Transfer modes - FAST transfer mode - REAL-TIME FAST transfer mode - IN-PHASE transfer mode - RES-VOLT transfer mode - LONG-TIME transfer mode · Single busbar and segmented single busbar supported · High speed contact with approx.1ms for closing · Permission of bi-direction switching settable · Low voltage load-shedding settable · CB de-coupling when OPEN failed · NORMAL start locally or remotely · Manual CB closing to block HSBT · ON/OFF set locally or remotely · HSBT test mode supported
Protection functions for tie-CB · Overcurrent protection · Ground overcurrent protection · Overcurrent protection for busbar energization · Ground overcurrent protection for busbar energization
Monitoring functions · Self-supervision of the device · Oscillographic fault recording · Phase sequence of busbar voltage · Voltage circuit of busbar and line
Communication interfaces · PC front port for setting with DIGSI 4 · System interface
- IEC 60870-5-103, redundant optional - IEC 61850, Ethernet - PROFIBUS DP or Modbus RTU · Service interface for DIGSI 4 (modem) · Time synchronization via IRIG B/DCF 77

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Siemens SIP · Edition No. 8 11/53

Generator Protection/7VU683
Application

Application
The 7VU683 high speed busbar transfer (HBST) device of SIPROTEC 4 family is compact multifunction unit which has been developed for very fast power supply transfer of busbar which is installed with big rotating loads. It accommodates the primary diagram of both single busbar and segmented single busbar. It incorporates all the necessary HSBT conditions and even some protection functions. It is specially suitable for the power supply transfer of:
· Coal-fired power station · Gas-fired power station · Combined cycle power station · Integrated gasification combined cycle (IGCC) power station · Nuclear power station · Chemical plant · Petrochemical plant · Refinery plant · Iron and steel plant · Cement plant
The numerous other additional functions assist the user in ensuring the cost effective system management and reliable power supply. Local operation has been designed according to economic criteria. A large, easy-to-use graphic display is a major design aim.

HSBT function
In station service system of thermal power station and some industrial plants, a lot of asynchronous motor are connected. The restarting motors after some seconds power loss will cause heavy starting current and system voltage drop. On the other hand, the incorrect reconnecting to stand-by power source will even damage the winding of rotor.
The version HSBT 7VU683 is designed for this case. It will evaluate the necessary switching conditions to ensure the fast but secure transfer. Some improvements like as REAL-TIME FAST transfer mode, additional line current criteria will significantly help to the efficiency and safety.
Protection functions for tie-CB
The integrated protections are intend to protect the tie-CB in segmented single busbar diagram against short-circuit or ground fault.
Some special concerning is done to the busbar switch-onto-fault. Protection functions will only be active for a settable time.
Programmable logic
The integrated logic characteristics (CFC) allow the user to implement their own functions and generate user-defined messages.
Measuring values
The measuring values like as U, I, f, dV, df, dj, 3I0, 3V0 and CB closing time can be recorded and displayed.

Fig. 11/55 Function diagram 11/54 Siemens SIP · Edition No. 8

Generator Protection/7VU683
Construction

Function
Line1->Line2 Line2->Line1 Busbar1->Busbar2 Busbar2->Busbar1 Busbar1->Line1 Busbar2->Line2
Definite overcurrent protection Ground-overcurrent protection Overcurrent protection for busbar energization Ground-overcurrent protection for busbar energization
Phase sequence Voltage circuit Table 11/8 Functional scope of HSBT 7VU683

Abbreviation HSBT

ANSI C o d e

Protection I>+V< 3I0>+3V0> I>+V< 3I0>+3V0>
Supervision

50 50N 50.en 50N.en
47

2 Line-CBs X X
X X

2 Line-CBs + 1 Tie-CB
X X X X X X
X X X X
X X

Construction
The SIPROTEC 4 units have a uniform design and a degree of functionality which represents a whole new quality. Local operation has been designed according to ergonomic criteria. Large, easy-to read displays were a major design aim. The device HSBT 7VU683 is equipped with a graphic display thus providing and depicting more information especially in industrial applications. The DIGSI 4 operating program considerably simplifies planning and engineering and reduces commissioning times.
1/1-rack size is the available housing width of the device HSBT 7VU683, referred to a 19" module frame system. The height is a uniform 245 mm. Only flush-mounting housing with screw type terminals is available. All cables can be connected with or without ring lugs.
Fig. 11/56 Rear view with wiring terminal safety cover and serial interface

Siemens SIP · Edition No. 8 11/55

Generator Protection/7VU683
HSBT functions

HSBT functions
Starting conditions
The device HSBT 7VU683 is designed to support the following staring conditions,
NORMAL condition FAULT condition Inadmissible Under-voltage condition Inadmissible Under-frequency condition Inadvertent CB Open condition
The above conditions can be freely combined together, i.e, one of them can be individually switched "OFF".
· NORMAL condition
Under the NORMAL condition, the power system is fault free and the starting command must be manually issued. This command can come from remote control center and/or local controller via wiring connection or communication over protocol, e.g,
DCS of power station Turbine control system Local panel
The switching of remote and local starting authority is done by internal CFC logic and controlled by device switching key "Remote/Local". The starting command can only be remotely executed over communication when the switching key is at position "Remote", vice versa.
· FAULT condition
Under the FAULT condition, power system fault must be there on the in-feeder line and the starting command must be externally issued by other device, e.g, protection device.
· Abnormal condition
Under the abnormal condition, voltage disturbance must be there on the busbar due to any causes. The starting command can be internally issued by device HSBT 7VU683 according to the following abnormal conditions
Inadmissible Under-voltage Inadmissible Under-frequency Inadvertent CB Open
To secure the starting reliability, line current is used as the additional criterion to the above conditions.
In case the operating CB is manually tripped, transfer must not be started. This can be recognized via indication 17864 ">NonManu.Op.CB1" and 17865 ">NonManu.Op.CB2" in configuration matrix.

Switching sequences
The category HSBT 7VU683 is designed to serve for the following switching sequences according to CBs' operating behavior,
PARALLEL switching sequence SIMULTANEOUS switching sequence SEQUENTIAL switching sequence
PARALLEL and SIMULATEOUS switching sequences can exclusively support the starting condition NORMAL while SEQUENTIAL can support all starting conditions.
· PARALLEL switching sequence
If the two sources are allowed to work on busbar in parallel for a short time, the PARALLEL sequence can be used for power supply transfer.
Under PARALLEL sequence, HSBT 7VU683 will firstly issue a CLOSE command to the to-be-closed CB after the device get the starting command. When the closure is successful, the device will trip the to-be-opened CB. The tripping command can be automatically generated by device or derived from manual operation which are dependent on setting,
PARALLEL Auto sequence PARALLEL Half-Auto sequence
Under PARALLEL Auto sequence, the device will automatically issue an OPEN command after a settable time delay when the closure is successful. Under PARALLE Half-Auto sequence, the device will not issue the OPEN command until the Manual Open command arrived. The criterions are as below,
df < 8851 "PARAL. Delta f" |dU| < 8852 "PARAL. Delta U" dj < 8853 "PARAL. Delta PHI"
If the to-be-opened CB failed to open, the device will automatically de-couple the to-be-closed CB.
The time sequence under PARALLEL can be understandable via Fig. 11/104 (assumed switching of closing CB2 and opening CB1).

11/56 Siemens SIP · Edition No. 8

Generator Protection/7VU683
HSBT functions

Starting Command

t action

Command

"1"

"0"

tCB2-closing

toverlapping

"1" CB2 Status
"0"

tCB1-opening

"1" CB1 Status
"0"

tCB1 Open Delay

"1"

OPEN

Command

"0 "

Starting Command

t action

tBB-dead

"1 "

OPEN

"0 "

tCB1-opening

Command

"1 "

CB1 Status
"0 " tCB2 Close Delay
"1 "

"0 "

Command

"1 " CB2 Status "0 "

tCB2-closing

Fig. 11/57 Time sequence of PARALLEL

Fig. 11/58 Time sequence of SIMULTANEOUS

The advantage of PARALLEL sequence is to avoid any interruption of busbar power supply. PARALLEL Auto sequence should be preferred to reduce the overlapping time of two sources.
· SIMULTANEOUS switching sequence
If the two sources are not allowed to work on busbar in parallel, the SIMULTANEOUS sequence can be used for power supply transfer.Under SIMULTANEOUS sequence, HSBT 7VU683 will firstly issue a OPEN command to the to-be-opened CB after the device gets the starting command. Meanwhile, the device will issue a CLOSE command to the to-be-closed CB if other criterions are met. The overlapping can be avoided via the settable CB close time delay if CB making time is small than breaking time. The criterions are as below,
df < 8855 "SIMUL. Delta f" dj< 8856 "SIMUL. Delta PHI"
If the to-be-opened CB failed to open, the device will automatically de-couple the to-be-closed CB.
The time sequence under SIMULTANEOUS can be understandable via Fig. 11/105 (assumed switching of closing CB2 and opening CB1).

Due to the different operating time of the CB (a CB normally opens faster than it close), the power supply of busbar will be interrupted for a few milliseconds. The length of this dead interval depends on the difference of CB operating time.
· SEQUENTIAL switching sequence
Under SEQUENTIAL sequence, HSBT 7VU683 will firstly issue a OPEN command to the to-be-opened CB after the device get the starting command. Differentiate from PARALLEL and SIMULTANEOUS switching sequences, SEQUENTIAL sequence can only issue CLOSE command after the opening succeeded.
The time sequence under SEQUENTIAL can be understandable via Fig. 11/106 (assumed switching of closing CB2 and opening CB1).

Starting Command
taction

"1 "

"0 "

tCB1-opening

"1 "

"0 "
" 1 " CLOSE Command
"0 "

"1 " CB1 Status
"0 "

tBB-dead
OPEN Command CB2 Status
t operating tCB1-closing

Fig. 11/59 Time sequence of SEQUENTIAL

Siemens SIP · Edition No. 8 11/57

Generator Protection/7VU683
HSBT functions

Transfer modes
In the station service system of power station and industrial plants, lots of asynchronous motors are connected. In case of the main source interruption, the residual voltage of busbar will be induced by connected asynchronous motors. Fig.11/107 shows the well-known typical diagram of vector trajectory of residual voltage.

210° 180°
150°

Un-safe Area

270° 240°

B III

C
0.4s 0.6s

300°

Safe Area RETArLa-sTnIMfeEr FAST
330° IV
V Uref

0.8s

0.5s

0.1s

30°

0.2s

IN-PHASE Transfer

The equivalent circuit of residual voltage Ures and referred voltage Uref is shown in Fig. 11/109.

The voltage drop on motor Um at instant of CB closing is calculated by following,

Um = dU · xm /(xm +xs) = k · dU

(Equa.-1)

Here, xm and xs are respectively the equivalent reactance of busbar loading and referred system.

~ Uref

Ures ~

120° Ures

60°
0.7s 0.3s

TraFnsAfSerT

90° REAL-TTrIaMnEsfeFrAST
Fig. 11/60 Vector trajectory of residual voltage Some notes are there regarding curve A according to Fig. 11/110. The amplitude and frequency of residual voltage will decrease regarding time, while the delta phase angle against referred voltage will increase. Fig. 11/108 gives more messages to differential voltage.
Fig. 11/61 Vector trajectory of residual voltage

Fig. 11/62 Equivalent circuit of dU

For safety reason, the value |Um| must not exceed the permissible voltage ko/v · |Un.|, Then, the maximum of permissible differential voltage |dU|max will be,

|dU|max = ko/v /k · |Un|

(Equa.-2)

In case ko/v = 1.1 and k = 0.67, the calculated |dU|max should be less than 1.64 · |Un| (refer to curve B in Fig. 11/107). In case ko/v = 1.1 and k = 0.95, the calculated |dU|max should be less than 1.15 · |Un| (refer to curve C in Fig. 11/107). This calculation result would be the base for setting.

The plane is divided into two parts by curve B (or curve C). The left is defined as un-safe area because the value |dU| is bigger than the up-limit |dU|max which could damage the winding of stator. Vice versa, the right is safe area.

Based on the above principles, the category HSBT 7VU683 is designed to have the following modes (refer to Fig. 11/107) to fit for the safe transfer,

FAST transfer mode (area I) REAL-TIME FAST transfer mode (area II and IV) IN-PHASE transfer mode (area V) RES-VOLT transfer mode LONG-TIME transfer mode

11/58 Siemens SIP · Edition No. 8

Generator Protection/7VU683
HSBT functions

All of above modes can be freely combined together, i.e, one of them can be individually switched "ON" or "OFF" remotely via communication or locally at device panel.
To be noted that the original dj and |dU| between busbar voltage and standby voltage due to wiring can be automatically compensated by device during configuration.
· FAST transfer mode
The study and testing results show, in most cases the typical values of df, dj and |dU| are smaller enough within the first tens of millisecond from the instant the CB opens. It's good to safe and fast transfer due to the slight shock to motors. If the real-time measured df, dj and |Ures| meet the defined criterions, the device will immediately issue the CLOSE command to the to-be-closed CB. The criterions are as below,
df < 8858 "FT Delta f" dj < 8859 "FT Delta PHI" |Ures| > 8860 "FT U/V BLK"
The typical operating time of 7VU683 in this case is approx. 20ms. As modern vacuum breaker has less making time, e.g, 60ms, the dead time of busbar will be as short as approx. 80ms.
· REAL-TIME FAST transfer mode
When FAST transfer chance is missed, the device will automatically, if activated, turn to next transfer mode REAL-TIME FAST.
This mode has more concerning on the permissible motor voltage, i.e, the differential voltage |dU| across the opened CB must not exceed the value |dU|max. The intelligent device 7VU683 then estimates the delta phase angle dj and differential voltage dU at the instant the CB closes based on real-time slipping rate and the settable "CBx Closing Time". If all the quantity of predicted dj and dU, the real-time df and |Ures| meet the defined criterions, the device will immediately issue the CLOSE command to the to-be-closed CB. The criterions are as below,
df < 8861 "RTFT Delta f" |dU| < 8862 "RTFT Delta U" dj< 8863 "RTFT Delta PHI" |Ures| > 8864 "RTFT U/V BLK"

· IN-PHASE transfer mode
When the residual voltage comes close to the referred voltage, it comes to transfer mode IN-PHASE. It's good for safe transfer if the CB closes at the instant the value dj is zero.
The intelligent device 7VU683 estimates the delta phase angle dj at the instant the CB closes. based on real-time slipping rate and the settable "CBx Closing Time". If If all the quantity of predicted dj, the real-time df and |Ures| meet the defined criterions,, the device will immediately issue the CLOSE command to the to-be-closed CB. The criterions are as below,
df < 8868 "IN-PHA Delta f" dj < 8869 "IN-PHA Delta PHI" |Ures| > 8870 "IN-PHA U/V BLK"
· RES-VOLT transfer mode
If the above mentioned transfer modes failed, the transfer can still go on with mode RES-VOLT.
When the residual voltage |Ures| under-shots the settable parameter 8871 "RES-VOLT Threshold", the RES-VOLT transfer mode will perform and the device will immediately issue the CLOSE command to the to-be-closed CB. The typical setting could be 30%Un.
To reduce the shock under low voltage restarting of motors, two stages of Low Voltage Load-Shedding (LVLSH) function are integrated in the device. LVLSH will pickup before the RES-VOLT transfer mode. This function can be activated or de-activated manually on site.
· LONG-TIME transfer mode
The last criterion to start the transfer is LONG-TIME mode if all above mentioned modes failed.
When the transfer time is more than the settable parameter 8872 "LONG-TIME Threshold", the LONG-TIME transfer mode will perform and the device will immediately issue the CLOSE command to the to-be-closed CB. The typical setting could be 3s.

Siemens SIP · Edition No. 8 11/59

Generator Protection/7VU683
HSBT functions

Switching directions
The device support bi-direction power transfer under NORMAL condition, i.e, the device can transfer the main source of busbar to standby depending on the actual CBs' status, vice versa.
In most cases, the switching is limited from main source to standby source under starting conditions of FAULT, Inadmissible Under-voltage, Inadmissible Under-frequency and Inadvertent CB Open. The requirement can be met by set the parameter 8831 "Mono-direction against NORMAL condition" = "YES". The default setting "YES" can be changed to "NO" if bi-direction transfer is always required in any conditions.

To be noted that power supply 1 is exclusively defined as main source while power supply 2 defined as standby source. Then, if mono-direction against NORMAL condition is required, power supply 1 in Fig. 11/121 to Fig. 11/128 should be identified as main source.
The transfer permission under various starting conditions and switching directions can be referred to below two tables.

CB1 Status
Closed Open

CB2 Status
Open Closed

Switching-over

From

Voltage Comparison
U_B U_L2 U_B U_L1

Busbar Transfer Permitted?

NORMAL FAULT

Inadmissible Undervoltage

Yes

No1)

1) If parameter 8831 "Mono-direction against NORMAL" = "YES", this cell says No. Otherwise, this cell says Yes.

Inadmissible Underfrequency Yes
No1)

Inadvertent CB Open Yes
No1)

Table 11/9 Transfer permission under default setting, single busbar

CB1 Status
Closed Closed Open

CB3 Status
Closed Open Closed

CB2 Status
Open Closed Closed

Switchingover
From To

Voltage Comparison

U_B2 U_B2 U_B1 U_B2 U_B1 U_B1

U_L2 U_L2 U_B2 U_B1 U_L1 U_L1

Busbar Transfer Permitted?

NORMAL
Yes Yes Yes Yes Yes Yes

FAULT
Yes / 2) Yes No1) No1) / 2)

Inadmissible Undervoltage Yes / 2)
Yes No1) No1) / 2)

1) If parameter 8831 "Mono-direction against NORMAL" = "YES", this cell says No. Otherwise, this cell says Yes. 2) Not applicable for this cell

Table 11/10 Transfer permission under default setting, segmented single busbar

Inadmissible Underfrequency Yes / 2)
Yes No1) No1) / 2)

Inadvertent CB Open Yes / 2)
Yes No1) No1) / 2)

11/60 Siemens SIP · Edition No. 8

Generator Protection/7VU683
HSBT functions

HSBT test mode
To facilitate the functional testing and site commissioning, the Test Mode is specially designed for this purpose. This function can be activated on site by parameter setting 8820 "HSBT Test Mode" = "Yes" or by indication 18020 ">HSBT Test Mode" via binary input.
If the function HSBT goes into Test Mode, the transfer process is the same except that the CLOSE command will be blocked. Instead, CLOSE command with test mark will be issued for indicating.
HSBT Test Mode could be helpful before the device is put into service. When CB is manually tripped, HSBT 7VU683 picks up and goes into transfer process. Under the assistance of integrated Fault Recorder and Event Log, the operating consequence and settings can be assessed. Optimization to parameter settings can be done based on the assessment.

Sample of oscillographic FAST transfer Fig. 11/64 Oscillographic FAST transfer at segmented single busbar

8819 HSBT Test Mode
ON "1"
OFF
18020 >HSBT Test Mode

OR
CLOSE CB1
CB2 CB3

AND AND

17767 CommandCloseCB1 17768 CommandCloseCB2 17769 CommandCloseCB3
18021 Cnd.Cl.CB1.Test 18022 Cnd.Cl.CB2.Test 18023 Cnd.Cl.CB3.Test

Fig. 11/63 Logic diagram of test mode
Reset of transfer
The default setting is to block the device after once transfer is executed, i.e, either failure or success, the device goes into blocking status till to the reset indication via binary input or LED button on device panel. This can be changed by setting the parameter 8817 "Manual Restart HSBT" = "NO". Then, after once successful transfer, the device will automatically execute a new transfer request before the reset indication arrives. But, after once failed transfer, the device will go into blocking status till to the reset indication.

Fig. 11/65 Trip log of FAST transfer at segmented single busbar
Some notes to the two figures, Primary connection of segmented single busbar Line1 in operating while Line2 in standby, CB3 serve as tie-CB
which is in closed status Fault is there in Line1 and cleared by protection relay. Mean-
while, HSBT is started Switching-over between Line1 and Line2 are defined Instant 0ms, device picked up, CommandOpenCB1 issued Instant 12ms, CB1 opened Instant 26ms, CommandCloseCB2 issued Instant 62ms, CB2 closed FAST transfer succeeded, approx. 50ms dead time interval of
busbar

Siemens SIP · Edition No. 8 11/61

Generator Protection/7VU683
Protection functions

Protection functions
The Power Supply Transfer device 7VU68 integrates protection functions for tie-CB in primary connection of Segmented Single Busbar. This function can be set "Enabled" or "Disabled" during configuration.
The protection include the following functions, Phase overcurrent protection Ground overcurrent protection Phase overcurrent protection for Busbar Energization Ground overcurrent protection for Busbar Energization
To secure the reliability and sensitivity, the voltage element is additionally introduced to current criterion to release trip command.
For functions of Phase-overcurrent protection and Phase overcurrent for Busbar Energization, compound voltage element is used. The criterion of compound voltage element is illustrated in Fig. 11/113.

Busbar1 U2
Busbar1 Uab Busbar1 Ubc Busbar1 Uca

9003 U2 Over-voltage

9002 Ph-ph Under-voltage

Compound Voltage

Fig. 11/66 Logic of compound voltage element
For functions of ground overcurrent protection and ground overcurrent protection for Busbar Energization, the element of zero sequence over-voltage is used. The quantity is derived from calculated 3U0 based on measured busbar1 voltage.
The validity of protections in case of busbar energization can be set under parameter 9019A "Active Time for Busbar Energization".
Each of above functions can be separately switched "ON" or "OFF" remotely via communication or locally at device panel.

Phase-overcurrent protection
This function is designed to detect any short-circuit faults in MV system. The device will evaluate all current inputs at channel I_B and will pickup immediately if one of phase current over-shots the settable threshold.
The function has two stages, one time delay for each stage.
The voltage element can be activated or de-activated under parameter 9001 "Compound Voltage Control".
Ground-overcurrent protection
This function is designed to detect ground fault in MV system. The device will evaluate zero sequence current and will pickup immediately if it over-shots the settable threshold.
The quantity of zero sequence current is derived from calculated 3I0 or measured ground current Ie. This can be set under parameter 9018 "3I0/Ie Assignment".
The function has two stages, one time delay for each stage.
The voltage element can be activated or de-activated under parameter 9011 "3U0 Control".
Phase-overcurrent protection for busbar energization
To avoid any switch-onto-fault, the function phase-over-current protection can be activated for some time after the busbar is energized when tie-CB is closed. An individual function phase-overcurrent protection for busbar energization is specially designed for this utilization.
The function has the same criterion and stages to phase- overcurrent protection. The function will not be activated until the tie-CB is closed.
Ground-overcurrent protection for busbar energization
To avoid any switch-onto-fault, the function ground-over-current protection can be activated for some time after the busbar is energized when tie-CB is closed. An individual function groundovercurrent protection for busbar energization is specially esigned for this utilization.
The function has the same criterion and stages to ground- overcurrent protection. The function will not be activated until the tie-CB is closed.

11/62 Siemens SIP · Edition No. 8

Generator Protection/7VU683
Communication

Communication
With respect to communication, particular emphasis has been placed on high levels of flexibility, data integrity and utilization of standards common in energy automation. The design of the communication modules permits interchangeability on the one hand, and on the other hand provides openness for future standards (for example, Industrial Ethernet).
Local PC interface
The PC interface from the front of the unit permits quick access to all parameters and fault event data. The use of the DIGSI 4 operating program during commissioning is particularly advantageous.
Rear mounted interface
At the rear of the unit there is one fixed interface and two communication modules which incorporate optional equipment complements and permit retrofitting. They assure the ability to comply with the requirements of different communication interfaces (electrical or optical) and protocols (IEC 60870, PROFIBUS, DIGSI). The interfaces make provision for the following applications:
Service interface (fixed)
In the RS485 version, several protection units can be centrally operated with DIGSI 4. By using a modem, remote control is possible. This provides advantages in fault clearance, in particular in unmanned substations.
System interface
This is used to communicate with a control or protection and control system and supports, depending on the module connected, a variety of communication protocols and interface designs. Furthermore, the units can exchange data through this interface via Ethernet and IEC 61850 protocol and can also be operated by DIGSI.
IEC 61850 protocol
As of mid-2004, the Ethernet-based IEC 61850 protocol is the worldwide standard for protection and control systems used by power supply corporations. Siemens is of the first manufacturer to support this standard and has 200.000 IEC61850 devices in operation. By means of this protocol, information can also be exchanged directly between bay units so as to set up simple masterless systems for bay and system interlocking. Access to the units via the Ethernet bus will also be possible with DIGSI.

IEC 60870-5-103
IEC 60870-5-103 is an internationally standardized protocol for communication in the protected area. IEC 60870-5-103 is supported by a numerous of manufacturers and is used worldwide.
PROFIBUS DP
PROFIBUS is an internationally standardized communication system (EN 50170). PROFIBUS is supported internationally by several hundred manufacturers and has to date been used in more than 1,000,000 applications all over the world. With the PROFIBUS DP, the device can be directly connected to a SIMATIC S5/S7. The transferred data are fault data, measured values and information from or to the logic (CFC).
MODBUS RTU
MODBUS is also a widely utilized communication standard and is used in numerous automation solutions.
Safe bus architecture
· RS485 bus
With this data transmission via copper conductors, electromagnetic interference influences are largely eliminated by the use of twisted-pair conductor. Upon failure of a unit, the remaining system continues to operate without any faults.
· Fiber-optic double ring circuit
The fiber-optic double ring circuit is immune to electromagnetic interference. Upon failure of a section between two units, the communication system continues to operate without disturbance.
Substation controller

SIPROTEC

Fig. 11/67 IEC 60870-5-103: Radial electrical or fiber-optic connection

Siemens SIP · Edition No. 8 11/63

Generator Protection/7VU683
High Speed Busbar Transfer Communication

DIGSI

Option: SICAM PAS

Control center

Switch

SIPROTEC

Fig. 11/68 Bus structure for station bus with Ethernet and IEC 61850, fiber-optic ring

Fig. 11/69 Optical Ethernet communication module for IEC 61850 with integrated Ethernet-switch

Fig. 11/70 PROFIBUS communication module, optical, double ring

Fig. 11/71 Fiber-optic communication module

11
Fig. 11/72 R S232/RS485 electrical communication module

11/64 Siemens SIP · Edition No. 8

Generator Protection/7VU683
High Speed Busbar Transfer Communication

System solution
SIPROTEC 4 is tailor-made for use in SIMATIC-based automation systems.
Via the PROFIBUS DP, indications (pickup and tripping) and all relevant operational measured values are transmitted from the HSBT device.
Via modem and service interface, the electric engineer has access to the protection devices at all times. This permits remote maintenance and diagnosis (cyclic testing).

Parallel to this, local communication is possible, for example, during a major inspection. For IEC 61850, an interoperable system solution is offered with SICAM PAS. Via the 100 Mbit/s Ethernet bus, the unit are linked with PAS electrically or optically to the station PC. The interface is standardized, thus also enabling direct connection of units of other manufacturers to the Ethernet bus. With IEC 61850, however, the units can also be used in other manufacturers' systems.

Operation and monitoring

Automation systems (e.g. SIMATIC)

PROFIBUS-DP

SS
7VU68

SIPROTEC

7VU68

SIPROTEC

7VU68

DIGSI 4 (Local for commissioning)

RS485/ optical converter RS232/ optical converter
Comm. Modem network Modem
DIGSI 4 (Remote control via modem)

Fig. 11/73 System solution: communication

Siemens SIP · Edition No. 8 11/65

Generator Protection/7VU683
High Speed Busbar Transfer Typical applications

Typical applications
Primary connection of single busbar The device HSBT 7VU683 will automatically determine the switching direction based on the actual CBs' status.

Each switching-over can be individually switched "ON" or "OFF" remotely via communication or locally at device panel.

Main Source
PT1
Line1/L1

Ix_L1

BO6

Ux_L1

R13

R14

Ua_B

Ub_B

Uc_B

Switching Direction L1->L2
HSBT 7VU683

K14

Ux_L2

K13

BO11

Ix_L2

Stand-by Source PT2
Line2/L2

Close
J6 J5
CT2

R16

R18

R17

R15

CT1
J1 J2
Open

CB1

Fig. 11/74 Switching-over L1->L2, single busbar

Main Source

R14

R13

Ux_L1

PT1 Line1/L1

BO10

Ix_L1

Ua_B

Ub_B

Uc_B

Busbar
Switching Direction L2->L1
HSBT 7VU683

K14

Ux_L2

K13

BO13

Ix_L2

CB2
Stand-by Source PT2
Line2/L2

Open
J6 J5
CT2

R16

R18

R17

R15

CT1
J1 J2
Close

CB1 Fig. 11/75 Switching-over L2->L1, single busbar 11/66 Siemens SIP · Edition No. 8

Busbar

CB2

Generator Protection/7VU683
High Speed Busbar Transfer Typical applications

Primary connection of segmented single busbar: CB1 and CB3 are closed, CB2 is opened
In case of these CBs' status, two possible switching directions are there. Then, the starting command of two switching directions must be externally separately routed to device's binary inputs, e.g, starting command L1->L2 routed to BI13, B2->L2 to BI12.

The device will properly execute the switching direction based on the command input under this case.
Each switching-over can be individually switched "ON" or "OFF" remotely via communication or locally at device panel.

Main Source
PT1

R13

R14

Switching Direction L1->L2
HSBT 7VU683

K14

K13

Stand-by Source
PT2

Ua_B2 Ux_L2

Ux_L1 Ua_B1

Ix_L2

BO11

Ub_B2

Uc_B2

Ie_B Ic_B Ib_B Ia_B

Uc_B1

Ub_B1

BO6

Ix_L1

Line1/L1

Line2/L2

Q8 Q7 Q5 Q6 Q3 Q4 Q1 Q2 K16 K18 K17 K15
Close
J6 J5
CT2

CT1
J1 J2
Open
R15 R17 R18 R16

CB1

Busbar1/B1

CB3

Fig. 11/76 Switching-over L1->L2, segmented single busbar

CT3

Main Source
PT1
Line1/L1

Ix_L1

Ux_L1 Ua_B1

R13

R14

Ub_B1

Uc_B1

BO5

Switching Direction B2->L2
HSBT 7VU683

Ie_B Ic_B Ib_B Ia_B

Uc_B2

Ub_B2

K14

Ua_B2 Ux_L2

K13

BO11

Busbar2/B2

CB2

Stand-by Source PT2
Line2/L2

Ix_L2

Q8 Q7 Q5 Q6 Q3 Q4 Q1 Q2 K16 K18 K17 K15
Close
J6 J5
CT2

CT1
J1 J2 R15 R17 R18 R16
Open

CB1

Busbar1/B1

CB3

Fig. 11/77 Switching-over B2->L2, segmented single busbar

CT3

Busbar2/B2

CB2

Siemens SIP · Edition No. 8 11/67

Generator Protection/7VU683
High Speed Busbar Transfer Typical applications

Primary connection of segmented single busbar: CB2 and CB3 are closed, CB1 is opened
In case of these CBs' status, two possible switching directions are there. Then, the starting command of two switching directions must be externally separately routed to device's binary inputs, e.g, starting command B1->L1 routed to BI13, L2->L1 to BI12. The device will properly execute the switching direction based on the command input under this case.

Starting command B1->L1 can be designated to BI13 too even if starting command L1->L2 is already there, the reason is only one of these two switching directions will be automatically executed by device based on the actual CBs' status. The same situation applies to L2->L1.
The above switching-overs can be individually switched "ON" or "OFF" remotely via communication or locally at device panel.

Main Source
PT1

R13

R14

Switching Direction L2->L1
HSBT 7VU683

K14

K13

Stand-by Source
PT2

Ua_B2 Ux_L2

Ux_L1 Ua_B1

Ix_L2

BO13

Ub_B2

Uc_B2

Ie_B Ic_B Ib_B Ia_B

Uc_B1

Ub_B1

BO10

Ix_L1

Line1/L1

Line2/L2

Q8 Q7 Q5 Q6 Q3 Q4 Q1 Q2 K16 K18 K17 K15
Open
J6 J5
CT2

CT1
J1 J2
Close
R15 R17 R18 R16

CB1

Busbar1/B1

CT3 CB3

Fig. 11/78 Switching-over L2->L1, segmented single busbar

Main Source
PT1
Line1/L1

Ix_L1

BO10

Ux_L1 Ua_B1

R13

R14

Ub_B1

Uc_B1

BO5

Switching Direction B1->L1
HSBT 7VU683

Ie_B Ic_B Ib_B Ia_B

Uc_B2

Ub_B2

K14

Ua_B2 Ux_L2

K13

Busbar2/B2

CB2

Stand-by Source PT2
Line2/L2

Ix_L2

Q8 Q7 Q5 Q6 Q3 Q4 Q1 Q2 K16 K18 K17 K15 J6 J5
CT2

CT1
J1 J2
Close
R15 R17 R18 R16
Open

CB1

Busbar1/B1

CT3 CB3

Fig. 11/79 Switching-over B1->L1, segmented single busbar 11/68 Siemens SIP · Edition No. 8

Busbar2/B2

CB2

Generator Protection/7VU683
High Speed Busbar Transfer Typical applications

Primary connection of segmented single busbar: CB1 and CB2 are closed, CB3 is opened
In case of these CBs' status, two possible switching directions are there. Then, the starting command of two switching directions must be externally separately routed to device's binary inputs, e.g, starting command B1->B2 routed to BI13, B2->B1 to BI12. The device will properly execute the switching direction based on the command input under this case.

Starting command B1->B2 can be designated to BI13 too even if starting command L1->L2 and B1->L1 are already there, the reason is only one of these three switching directions will be automatically executed by device based on the actual CBs' status. The same situation applies to B2->B1.
The above switching-overs can be individually switched "ON" or "OFF" remotely via communication or locally at device panel.

Main Source
PT1

R13

R14

Switching Direction B1->B2
HSBT 7VU683

K14

K13

Stand-by Source
PT2

Ua_B2 Ux_L2

Ux_L1 Ua_B1

Ix_L2

Ub_B2

Uc_B2

Ie_B Ic_B Ib_B Ia_B

BO12

Uc_B1

Ub_B1

BO6

Ix_L1

Line1/L1

Line2/L2

Q8 Q7 Q5 Q6 Q3 Q4 Q1 Q2 K16 K18 K17 K15 J6 J5
CT2

CT1
J1 J2
Open
R15 R17 R18 R16
Close

CB1

Busbar1/B1

CT3 CB3

Fig. 11/80 Switching-over B1->B2, segmented single busbar

Main Source Main Source
PT1

R13

Switching Direction B2->B1
Switching Direction B2->B1

R14 R14

Ux_LR113

PT1

HSBT 7VU683

Ux_L1 Ua_B1

Line1/L1

HSBT 7VU683

Ie_B Ie_B

BO12 BO12

Uc_B1 Uc_B1

Ub_B1 Ub_B1

Ix_L1 Ix_L1

Ua_B1

Line1/L1

Close Close

R15 R15 R17 R17 R18 R18 R16 R16

CT1 CT1

CB1 CB1

Busbar1/B1 Busbar1/B1

CT3

CB3

CT3

CB3

Fig. 11/81 Switching-over B2->B1, segmented single busbar

Q5 Q6 Q5 Q6 Q3 Q4 Q3 Q4 Q1 Q2 Q1 Q2

Ic_B Ib_B Ia_B

K16 K16 K18 K18 K17 K17 K15 K15

Uc_B2 Uc_B2

Ub_B2 Ub_B2

K14 K14

Ua_B2

Ua_B2 Ux_L2

Ux_LK213

K13

BO13 BO13

Open Open

Busbar2/B2

CB2

Stand-by Source Stand-by Source PT2
PT2
Line2/L2
Line2/L2

Ix_L2 Ix_L2

CT2 CT2

Busbar2/B2 Busbar2/B2

CB2 CB2

Siemens SIP · Edition No. 8 11/69

Generator Protection/7VU683
High Speed Busbar Transfer Selection and ordering data
Description

7VU683 high speed busbar transfer device Housing binary inputs and outputs Housing 1/1 19'', 17 BI, 18 BO (incl.5 High Speed), 1 live-status contact
Current transformer: In IN=1A1) IN=5A1)
Auxiliary Voltage DC 24 to 48 V, binary input threshold DC 19 V3) DC 60 to 125 V2), binary input threshold DC 19 V3) DC 110 to 250 V2), AC 115/230 V, binary input threshold DC 88 V3) DC 220 to 250 V2), AC 115/230 V, binary input threshold DC 176 V3)
Construction Flush-mounting housing, screw-type terminals
Region-specific default settings/ language Settings Region World, English4), 50/60Hz Region China, Chinese4), 50/60Hz

Port B: (System port on rear of device) No system port IEC 60870-5-103 Protocol, electrical RS232 IEC 60870-5-103 Protocol, electrical RS485 IEC 60870-5-103 Protocol, 820 nm fibre, ST-connector Profibus DP Slave, RS485 Profibus DP Slave, 820 nm fibre, double ring, ST-connector Modbus, RS485 Modbus, 820 nm fibre, ST-connector IEC 60870-5-103 Protocol, redundant RS485 IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45-connector IEC 61850, 100 Mbit Ethernet, with integrated switch optical, double, LC-connector
Port C (Service) Port C: DIGSI 4/Modem, electrical RS232; Port C: DIGSI 4/Modem/ RTD-box, electrical RS485;
Measuring/ fault recording Basic measured Values
Functions High Speed Busbar Transfer (HSBT) (2 or 3 circuit breakers) Protection functions (Overcurrent phase/ground (50, 50N); Overcurrent phase/ground for busbar energization Supervision functions
1) Rated current 1/5 A can be selected by means of jumpers. 2) Transition between the three auxiliary voltage can be selected by mean of jumpers. 3) The threshold of each binary input can be set via jumpers. 4) Device language can be selected via DIGSI.

11/70 Siemens SIP · Edition No. 8

Order No.

Short code

7VU683 - E -1 A A 0

1 5
2 4 5 6
E
B W

0 1 2 3 9 9 9 9 9 9 9
1 2
1
A

L0 A
B D E
P
R S

Description

Generator Protection/7VU683
High Speed Busbar Transfer Accessories
Order No.

Connecting cable Cable between PC/notebook (9-pin connector) and protection unit (9-pin connector) (contained in DIGSI 4, but can be ordered additionally)

7XV5100-4

Description

Order No.

Size of

Supplier

Fig.

package

Mounting rail Short-circuit link
Safety cover for terminals

For current terminals For other terminals
Large Small

C73165-A63-D200-1

C73334-A1-C34-1

C73334-A1-C31-1

C73334-A1-C32-1

1) Your local Siemens representative can inform you on local suppliers.

Siemens
Siemens Siemens
Siemens Siemens

11/129
11/130 11/131

Fig. 11/82 Mounting rail for 19" rack

Fig. 11/83 S hort-circuit link for current terminals

Fig. 11/84 S hort-circuit link for voltage terminals/ indications terminals

Siemens SIP · Edition No. 8 11/71

Generator Protection/7VU683
High Speed Busbar Transfer Connection diagram

Q1 Q2 Q3 Q4 Q5 Q6 Q7 Q8

J1 J2 J3 J4 J5 J6 J7 J8

R15 R17 R18 R16 R13 R14

K15 K17 K18 K16 K13 K14

R9 R10 R11 R12

P17

P18

N3 N4

N10

N11

N12

K9 K10 K11 K12

Ia_B Ib_B Ic_B

HSBT 7VU683

BI 1

BI 2

BI 3

BI 4

BI 5

Ie_B Ix_L1

BO 1 BO 2 BO 3

N/A

BO 4

Ix_L2

BO 5

N/A
Ua_B1 / Ua_B Ub_B1 / Ub_B Uc_B1 / Uc_B
Ux_L1
Ua_B2 Ub_B2 Uc_B2
Ux_L2

BO 62)
BO 71) BO 81) BO 91)
BO 102)
BO 112)
BO 122)
BO 132)

BI 6 BI 7
BI 8 BI 9 BI 10 BI 11 BI 12 BI 13 BI 14 BI 15
BI 16

BO 14 BO 15 BO 16

BO 17

BO 18

Life Status

Contact

Power Supply

=+
= (~) -

Service Port System Port Time Synchronization Front Operator

BI 17

1) Fast speed contact 2) High speed contact

Ground at rear of housing

F5 F6 F7 F8 F9 F10
R1 R2 R3 R4 R5 R6 R7 R8
P3 P4 P6 P7 P8 P5 P9 P10 P11 P12 P13 P14 P15 P16
K1 K2 K3 K4 K5 K6 K7 K8
F3 F4
F1 F2
C
B
A

Fig. 11/85 7VU683 connection diagram 11/72 Siemens SIP · Edition No. 8

Substation Automation

Page

SIPROTEC 6MD66 high-voltage bay control unit

12/3

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
12/2 Siemens SIP · Edition No. 8

Substation Automation/6MD66
SIPROTEC 6MD66 high-voltage bay control unit

Function overview

Fig. 12/1 SIPROTEC 6MD66 high-voltage bay control unit
Description
The 6MD66 high-voltage bay control unit is the control unit for high voltage bays from the SIPROTEC 4 relay series. Because of its integrated functions, it is an optimum, low-cost solution for high-voltage switchbays.
The 6MD66 high-voltage bay control unit also has the same design (look and feel) as the other protection and combined units of the SIPROTEC 4 relay series. Configuration is performed in a standardized way with the easy-to-use DIGSI 4 configuration tool.
For operation, a large graphic display with a keyboard is available. The important operating actions are performed in a simple and intuitive way, e.g. alarm list display or switchgear control. The operator panel can be mounted separately from the unit, if required. Thus, flexibility with regard to the mounting position of the unit is ensured. Integrated key-operated switches control the switching authority and authorization for switching without interlocking. High-accuracy measurement (± 0.5 %) for voltage, current and calculated values P and Q are another feature of the unit.

LSP2187-afp.eps LSP2187-afp.eps

Application · Integrated synchro-check for synchro-
nized closing of the circuit-breaker
· Breaker-related protection functions (Breaker Failure 50BF, Auto-reclosure 79)
· Automation can be configured easily by graphic means with CFC
· Flexible, powerful measured-value processing
· Connection for 4 voltage transformers, 3 current transformers, two 20 mA transducers
· Volume of signals for high voltage
· Up to 14 1 ½-pole circuit-breakers can be operated
· Up to 11 2-pole switching devices can be operated
· Up to 65 indication inputs, up to 45 command relays
· Can be supplied with 3 volumes of signals as 6MD662 (35 indications, 25 commands), 6MD663 (50 indications, 35 commands) or 6MD664 (65 indications, 45 commands); number of measured values is the same
· Switchgear interlocking
· Inter-relay communication with other devices of the 6MD66 series, even without a master station interface with higher level control and protection
· Suitable for redundant master station
· Display of operational measured values V, I, P, Q, S, f, cos (power factor) (single and three-phase measurement)
· Limit values for measured values
· Can be supplied in a standard housing for cubicle mounting or with a separate display for free location of the operator elements
· 4 freely assignable function keys to speed up frequently recurring operator actions
Communication interfaces · System interface
IEC 61850 Ethernet IEC 60870-5-103 protocol PROFIBUS DP Service interface for DIGSI 4 (modem) Front interface for DIGSI 4 Time synchronization via IRIG B/DCF 77

1 2 3 4 5 6 7 8 9 10 11 12 13

15
Siemens SIP · Edition No. 8 12/3

Substation Automation/6MD66
Application

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Application

Communication
With regard to communication between components, particular emphasis is placed on the SIPROTEC 4 functions required for energy automation.
· Every data item is time-stamped at its source, i.e. where it originates.
· Information is marked according to where it originates from (e.g. if a command originates "local" or "remote")
· The feedback to switching processes is allocated to the commands.
· Communication processes the transfer of large data blocks, e.g. file transfers, independently.
· For the reliable execution of a command, the relevant signal is first acknowledged in the unit executing the command. A check-back indication is issued after the command has been enabled (i.e. interlocking check, target = actual check) and executed.
In addition to the communication interfaces on the rear of the unit, which are equipped to suit the customer's requirements, the front includes an RS232 interface for connection of DIGSI. This is used for quick diagnostics as well as for the loading of parameters. DIGSI 4 can read out and represent the entire status of the unit online, thus making diagnostics and documentation more convenient.

Fig. 12/2 Connection diagram of the switching devices (circuit-breaker 2 poles closed, 1 pole open; disconnector/grounding switch 1½ pole)

Control

The bay control units of the 6MD66 series

have command outputs and indication

inputs that are particularly suited to the

Fig. 12/3 2-pole connection diagram of circuit-breakers and disconnectors

requirements of high-voltage technology.

As an example, the 2-pole control of a

switching device is illustrated (see Fig. 12/11). In this example,

two poles of the circuit-breaker are closed and 1 pole is open. All

other switching devices (disconnectors, grounding switches) are

closed and open in 1½-pole control. A maximum of 14 switching

devices can be controlled in this manner.

A complete 2-pole control of all switching devices (see Fig. 12/12) is likewise possible. However more contacts are required for this. A maximum of 11 switching devices can be controlled in this manner.

A possible method to connect the switching devices to the bay control unit 6MD66 is shown in Fig. 12/13. There it is shown how three switching devices Q0, Q1, and Q2 are connected using 1½ pole control.

15
12/4 Siemens SIP · Edition No. 8

Substation Automation/6MD66
Functions

Functions

Switchgear interlockings
Using the CFC (Continuous Function Chart) available in all SIPROTEC 4 units, the bay interlock conditions can, among other things, be conveniently configured graphically in the 6MD66 bay control unit. The inter-bay interlock conditions can be checked via the "inter-relay communication" (see next section) to other 6MD66 devices. With the introduction of IEC 61850 communication, the exchange of information for interlocking purposes is also possible via Ethernet. This is handled via the GOOSE message method. Possible partners are all other bay devices or protection devices which support IEC 61850- GOOSE message.
In the tests prior to command output, the positions of both key-operated switches are also taken into consideration. The upper key-operated switch corresponds to the S5 function (local/ remote switch), which is already familiar from the 8TK switchgear interlock system. The lower key-operated switch effects the changeover to non-interlocked command output (S1 function). In the position "Interlocking Off" the key cannot be withdrawn, with the result that non-operation of the configured interlocks is immediately evident.
The precise action of the key-operated switch can be set using the parameter "switching authority".
With the integrated function "switchgear interlocking" there is no need for an external switchgear interlock device.
Furthermore, the following tests are implemented (parameterizable) before the output of a command:
· Target = Actual, i.e. is the switching device already in the desired position?
· Double command lockout, i.e. is another command already running?
· Individual commands, e.g. grounding control can additionally be secured using a code.

Fig. 12/4 Typical connection for 1½-pole control

1 2 3 4 5 6 7 8 9 10

15
Siemens SIP · Edition No. 8 12/5

Substation Automation/6MD66
Functions

1 2 3 4 5 6 7 8 9 10 11 12 13

Synchronization

The bay control unit can, upon closing of the circuit-breaker, check whether the synchronization conditions of both partial networks are met (synchro-check). Thus an additional, external synchronization device is not required. The synchronization conditions can be easily specified using the configuration system DIGSI 4. The unit differentiates between synchronous and asynchronous networks and reacts differently upon connection:

In synchronous networks there are minor differences with regard to phase angle and voltage moduli and so the circuit-breaker response time does not need to be taken into consideration. For asynchronous networks however, the differences are larger and the range of the connection window is traversed at a faster rate. Therefore it is wise here to take the circuit-breaker response time into consideration. The command is automatically dated in advance of this time so that the circuit-breaker contacts close at precisely the right time.

Fig. 12/5 Connection of the measured values for synchronization

Fig. 12/14 illustrates the connection of the voltages.

As is evident from Fig. 12/14, the synchronization conditions are tested for one phase. The important parameters for synchronization are:

|Umin| < |U| < |Umax| (Voltage modulus)

< max (Angle difference)

f < fmax (Frequency difference)

Fig. 12/6 Voltage selection for synchronization with duplicate busbar system

Using the automation functions available in the bay control unit, it is possible to connect various reference voltages depending on the setting of a disconnector. Thus in the case of a double busbar system, the reference voltage of the active busbar can be automatically used for synchronization (see Fig. 12/15).

Alternatively the selection of the reference voltage can also take place via relay switching, if the measurement inputs are already being used for other purposes.

14 15
12/6 Siemens SIP · Edition No. 8

Fig. 12/7 Simultaneous connection of measured values according to a two-wattmeter circuit and synchronization

Substation Automation/6MD66
Functions

Synchronization

The bay control unit offers the option of storing various parameter sets (up

to eight) for the synchronization func-

tion and of selecting one of these for

operation. Thus the different properties of several circuit- breakers can be taken

into consideration. These are then used

at the appropriate time. This is relevant if

several circuit-breakers with e.g. different

response times are to be served by one

bay control unit.

LSP2493en.tif

The measured values can be connected

to the bay control unit in accordance with Fig. 12/14 (single-phase system) or

Fig. 12/8 "Power System Data", sheet for parameters of the synchronization function

Fig. 12/16 (two-wattmeter circuit).

The synchronization function can be

parameterized via four tabs in DIGSI.

LSP2496en.tif

8
Fig. 12/9 General parameters of the synchronization function
9

LSP2494en.tif

Fig. 12/10 Parameter page for asynchronous networks

11 12

LSP2495en.tif

Fig. 12/11 Parameter page for asynchronous networks

15
Siemens SIP · Edition No. 8 12/7

Substation Automation/6MD66
Communication

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

Communication

The device is not only able to communicate to the substation control level via standard protocol like IEC 61850, IEC 60870-5-103 or others. It is also possible to communicate with other bay devices or protection devices. Two possibilities are available.

Inter-relay-communication

The function "inter-relay-communication" enables the exchange of information directly between 6MD66 bay controller devices. The communication is realized via Port "C" of the devices, so it is independent from the substation communication port "B". Port "C" is equipped with a RS485 interface. For communication over longer distances, an external converter to fiber-optic cable can be used.
An application example for inter-relaycommunication is shown in Fig. 12/22. Three 6MD66 devices are used for control of a 1½ circuit-breaker bay. One device is assigned to each of the three circuitbreakers. By this means, the redundancy of the primary equipment is also available on the secondary side. Even if one circuit-breaker fails, both feeders can be supplied. Control over the entire bay is retained, even if one bay control unit fails. The three bay control units use the interrelay-communication for interchange of switchgear interlocking conditions. So the interlocking is working completely independent from the substation control level.

Fig. 12/12 Typical application: 1½ circuit-breaker method (disconnector and grounding switch not shown)
Fig. 12/13 Connection matrix of inter-relay communication in DIGSI 4

LSP2227f.tif

IEC 61850-GOOSE

With the communication standard IEC 61850, a similar function like interrelay-communication is provided with the "GOOSE" communication to other IEC 61850-devices. Since the standard IEC 61850 is used by nearly all SIPROTEC devices and many devices from other suppliers, the number of possible communication partners is large.

The applications for IEC 61850-GOOSE are

quite the same as for inter-relay-commu-

nication. The most used application is the

interchange of switchgear interlocking

information between bay devices. GOOSE Fig. 12/14 Connection for IEC 61850-GOOSE communication

uses the IEC 61850 substation Ethernet,

so no separate communication port is needed.The configuration is shown in Fig. 12/23. The SIPROTEC devices are connected via optical Ethernet and grouped by voltage levels (110 kV and 20 kV). The devices in the same voltage level can interchange

Like inter-relay-communication, GOOSE also supplies a status information for supervision of the communication. In case of interruption, the respective information is marked as "invalid".

the substation-wide interlocking information. GOOSE uses the

Therefore, non-affected information still can be used for inter-

substation Ethernet.

locking, and a maximum functional availability is guaranteed.

12/8 Siemens SIP · Edition No. 8

Measured-value processing
Measured-value processing is implemented by predefined function modules, which are likewise configured using DIGSI 4.
The transducer modules are assigned in the DIGSI 4 assignment matrix to current and voltage channels of the bay control unit. From these input variables, they form various computation variables (see Table 12/1).

Substation Automation/6MD66
Functions
1 2 3

LSP2228f.tif

Fig. 12/15 DIGSI 4 Parameter view transducer packets

The individual transducer modules can be

Name of the

Max. availability of Required input

Calculated variables

activated in the functional scope of the

transducer module transducers on the channels

(= output variables)

unit and will then appear in the DIGSI 4

unit (can be set via

assignment matrix with the input chan-

the functional scope)

nels and output variables from Table 1. The output variables can then be assigned

Transducer V

x 1

V, f

to the system interface or represented

Transducer I

x 1

I, f

in the measured value window in the display.

Transducer packet

x 3

1 phase

V, I

V, I, P, Q, S, , cos (PF), sin , f

Transducer packet

x 1

3 phase

V1, V2, V3, I1, I2, I3 V0, V1, V2, V3, V12,

V23, V31, I0, I1, I2, I3,

P, Q, S, , cos (PF), sin , f

Transducer packet

x 1

two-wattmeter circuit

V1, V2, I1, I2

Table 12/1 Properties of measured-value processing

V12, V13, I2, I3, P, Q, S, , cos (PF), sin , f
8

Sample presentation of the measured

value display.

LSP2189f.tif

Fig. 12/16

15
Siemens SIP · Edition No. 8 12/9

Substation Automation/6MD66
Functions

1 2 3 4 5 6 7 8 9 10 11 12 13

The connection of the input channels can be chosen without restriction. For the two-wattmeter circuit, the interface connection should be selected in accordance with Fig. 12/26. The two-wattmeter circuit enables the complete calculation of a three-phase system with only two voltage and two current transformers.

Fig. 12/17 Two-wattmeter circuit (connection to bay control unit)

Automation
With integrated logic, the user can set, via a graphic interface (CFC, Continuous Function Chart), specific functions for the automation of switchgear or substation. Functions are activated via function keys, binary input or via communication interface. Processing of internal indications or measured values is also possible.
Switching authorization/key-operated switch
The switching authorization (control authorization) (interlocked/ non-interlocked, corresponds to key-operated S1 in the 8TK interlock system) and the switching authority (local/remote, corresponds to key-operated S5 for 8TK) can be preset for the SIPROTEC 4 bay control unit using key-operated switches. The position of both keys is automatically evaluated by command processing. The key for operation without interlocks cannot be removed when in the position "non-interlocked", such that this mode of operation is immediately recognizable (see also page 12/15, Section "Switchgear interlockings").
Every change in the key-operated switch positions is logged.

Indication / measured value blocking
To avoid the transmission of information to the master unit during works on the bay, a transmission blocking can be activated.
Indication filtering
Indications can be filtered and delayed.
Filtering serves to suppress brief changes in potential at the indication input. The indication is passed on only if the indication voltage is still present after a set period of time. The filter time can be set from 0 to 24 hours in 1 ms steps. It is also possible to set the filter time so that it can, if desired, be retriggered.
Furthermore, the hardware filter time can be taken into consideration in the time stamp; i.e. the time stamp of a message that is detected as arriving will be predated by the known, constant hardware filter time. This can be set individually for every binary input in a 6MD66 bay control unit.

Chatter blocking
Chatter blocking feature evaluates whether, in a configured period of time, the number of status changes of indication input exceeds a specified figure. If exceeded, the indication input is blocked for a certain period, so that the communication line to the master unit will not be overloaded by disturbed inputs.
For every binary input, it is possible to set separately whether the chatter blocking should be active or not. The parameters (number of status changes, test time, etc.) can be set once per unit.

15
12/10 Siemens SIP · Edition No. 8

Substation Automation/6MD66
Functions

Auto-reclosure (ANSI 79)

The 6MD66 is equipped with an autoreclosure function (AR). The function includes several operating modes:

· Interaction with an external device for auto-reclosure via binary inputs and binary outputs; also possible with interaction via IEC 61850-GOOSE

· Control of the internal AR function by external protection

· 3-pole auto-reclosure for all types of faults; different dead times are available depending on the type of the fault

LSP2229f.tif

· 1-pole auto-reclosure for 1-phase faults, no reclosing for multi-phase faults

· 1-pole auto-reclosure for 1-phase faults and 2-phase faults, no reclosing for multi-phase faults.

Fig. 12/18 Parameterization of time management

· 1-pole auto-reclosure for 1-phase and 3-pole auto-reclosure for multi-phase faults
· 1-pole auto-reclosure for 1-phase faults and 2-phase faults and 3-phase auto-reclosure for multi-phase faults
· Multiple-shot auto-reclosure
· Interaction with the internal synchro-check
· Monitoring of the circuit-breaker auxiliary contacts
In addition to the above-mentioned operating modes, several other operating principles can be employed by means of the integrated programmable logic (CFC). Integration of autoreclosure in the feeder protection allows the line-side voltages to be evaluated. A number of voltage-dependent supplementary functions are thus available:
· DLC By means of dead-line-check (DLC), reclosure is effected only when the line is deenergized (prevention of asynchronous breaker closure)
· ADT The adaptive dead time (ADT) is employed only if autoreclosure at the remote station was successful (reduction of stress on equipment).
· RDT Reduced dead time (RDT) is employed in conjunction with auto-reclosure where no teleprotection method is employed: When faults within the zone extension but external to the protected line of a distance protection are switched off for rapid auto-reclosure (RAR), the RDT function decides on the basis of measurement of the return voltage from the remote station which has not tripped whether or not to reduce the dead time.

Breaker failure protection (ANSI 50BF)
The 6MD66 incorporates a two-stage circuit-breaker failure protection to detect failures of tripping command execution, for example, due to a defective circuit breaker. The current detection logic is phase-selective and can therefore also be used in single-pole tripping schemes. lf the fault current is not interrupted after a settable time delay has expired, a retrip command or a busbar trip command will be generated. The breaker failure protection can be initiated by external devices via binary input signals or IEC 61850 GOOSE messages.
Time management
The 6MD66 bay control units can, like the other units in the SIPROTEC 4 range, be provided with the current time by a number of different methods:
· Via the interface to the higher-level system control (PROFIBUS DP or IEC 61850)
· Via the external time synchronization interface on the rear of the unit (various protocols such as IRIG B and DCF77 are possible)
· Via external minute impulse, assigned to a binary input
· From another bay control unit by means of inter-relay communication
· Via the internal unit clock.
Fig. 12/27 illustrates the settings that are possible on the DIGSI interface.

1 2 3 4 5 6 7 8 9 10 11 12 13

15
Siemens SIP · Edition No. 8 12/11

Substation Automation/6MD66
Technical data

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

General unit data

Analog inputs

Rated frequency

50 or 60 Hz (adjustable, depending on the order number)

Rated current IN

1 or 5 A (can be changed via plugin jumper)

Rated voltage VN

100 V, 110 V, 125 V, 100 V3, 110 V3 can be adjusted using parameters

Power consumption
at IN = 1 A at IN = 5 A Voltage inputs

< 0.1 VA < 0.5 VA < 0.3 VA with 100 V

Measurement range current I

Up to 1.2 times the rated current

Thermal loading capacity

12 A continuous, 15 A for 10 s, 200 A for 1 s

Measurement range voltage V

Up to 170 V (rms value)

Max. permitted voltage

170 V (rms value) continuous

Transducer inputs

Measurement range

± DC 24 mA

Max. permitted continuous current ± DC 250 mA

Input resistance, recorded power loss at 24 mA

10 ± 1 % 5.76 mW

Power supply

Rated auxiliary voltages

DC 24 to 48 V, DC 60 to 125 V, DC 110 to 250 V

Permitted tolerance

-20 % to +20 %

Permitted ripple of the rated auxiliary voltage

15 %

Power consumption Max. at DC 60 to 250 V Max. at DC 24 to 48 V Typical at DC 60 to 250 V Typical at DC 24 to 48 V (typical = 5 relays picked up + live contact active + LCD display illuminated + 2 interface cards plugged in)

20 W 21.5 W 17.5 W 18.5 W

Bridging time at DC 24 and 60 V at DC 48 and 110 V

20 ms 50 ms

Binary inputs

Number

6MD662

6MD663

6MD664

Rated voltage range

DC 24 to 250 V (selectable)

Pick-up value (range can be set using jumpers for every binary input)

DC 17, 73 or 154 V

Function (allocation)

Can be assigned freely

Minimum voltage threshold (presetting)
for rated voltage 24, 48, 60 V for rated voltage 110 V for rated voltage 220, 250 V

DC 17 V DC 73 V DC 154 V

Maximum permitted voltage

DC 300 V

Current consumption, excited for 3 ms

approx. 1.5 mA approx. 50 mA to increase pickup time

Permitted capacitive coupling of the indication inputs

220 nF

Minimum impulse duration for message

4.3 ms

Output relay

Live contact

1 NC/NO (can be set via jumper: Factory setting is "Break contact", i.e. the contact is normally open but then closes in the event of an error)

Number of command relays, single pole
6MD662

25, grouping in 2 groups of 4, 1 group of 3, 6 groups of 2 and two ungrouped relays

6MD663

35, grouping in 3 groups of 4, 1 group of 3, 9 groups of 2 and two ungrouped relays

6MD664

45, grouping 4 groups of 4, 1 group of 3, 12 groups of 2 plus two ungrouped relays

Switching capacity, command

relay

Make

max. 1000 W/ VA

Break

max. 30 VA

Break (at L/R 50 ms)

25 VA

Max. switching voltage

250 V

Max. contact continuous current 5 A

Max. (short-duration) current 15 A

for 4 s

Switching capacity,

live contact ON and OFF

20 W/VA

Max. switching voltage

250 V

Max. contact continuous current 1 A

Max. make-time

8 ms

Max. chatter time

2.5 ms

Max. break time

2 ms

LED

Number

RUN (green)

ERROR (red)

Display (red), function can be 14

allocated

Unit design

Housing 7XP20

For dimensions drawings, see part 14

Type of protection acc. to

EN60529

in the surface-mounting

IP20

housing

in the flush-mounting housing

front

IP51

rear

IP20

Weight

Flush-mounting housing, integrated local control
6MD663 6MD664

approx. 10.5 kg approx. 11 kg

Surface-mounting housing, without local control, with assembly angle
6MD663 6MD664

approx. 12.5 kg approx. 13 kg

Detached local control

approx. 2.5 kg

12/12 Siemens SIP · Edition No. 8

Substation Automation/6MD66
Technical data

Electrical tests

Specifications

Standards

IEC 60255 (product standards) ANSI/IEEE C37.90.0/.1/.2 DIN 57435 Part 303

For further standards see specific tests

Insulation tests

Standards

IEC 60255-5 and IEC 60870-2-1

Voltage test (100 % test)

2.5 kV (rms), 50 Hz

All circuits except for auxiliary

supply, binary inputs,

communication and time synchro-

nization interfaces

Voltage test (100 % test) Auxiliary voltage and binary inputs

DC 3.5 kV

Voltage test (100 % test) only isolated communication and time synchronization interfaces

500 V (rms value), 50 Hz

Surge voltage test (type test) All circuits except for communication and time synchronization interfaces, class III

5 kV (peak); 1.2/50 s; 0.5 J; 3 positive and 3 negative surges at intervals of 5 s

EMC tests for noise immunity; type test

Standards

IEC 60255-6, IEC 60255-22 (product standards) EN 50082-2 (generic standard) DIN 57 435 Part 303

High frequency test

2.5 kV (peak value), 1 MHz; = 15 ms

IEC 60255-22-1, class III

400 pulses per s; duration 2 s

and DIN 57435 part 303, class III

Discharge of static electricity IEC 60255-22-2 class IV EN 61000-4-2, class IV
Exposure to RF field, nonmodulated IEC 60255-22-3 (report), class III

8 kV contact discharge; 15 kV air discharge; both polarities; 150 pF; Ri = 330
10 V/m; 27 to 500 MHz

Exposure to RF field, amplitude- 10 V/m; 80 to 1000 MHz; 80 % AM; modulated IEC 61000-4-3, class III 1 kHz

Exposure to RF field, pulse-

10 V/m; 900 MHz; repetition frequen-

modulated

cy 200 Hz; duty cycle 50 %

IEC 61000-4-3/ ENV 50204, class III

Fast transient interference bursts IEC 60255-22-4, IEC 61000-4-4, class IV

4 kV; 5/50 ns; 5 kHz; burst length = 15 ms; repetition frequency 300 ms; both polarities; Ri = 50 ; test duration 1 min

Oscillatory surge withstand capability ANSI/IEEE C37.90.1
Fast transient surge withstand capability ANSI/IEEE C37.90.1
Radiated electromagnetic interference ANSI/IEEE C37.90.2

2.5 to 3 kV (peak); 1 to 1.5 MHz
damped wave; 50 surges per second; duration 2 s; Ri = 150 to 200 4 to 5 kV; 10/150 ns; 50 impulses per second; both polarities; duration 2 s ; Ri = 80 35 V/m; 25 to 1000 MHz

Damped oscillations IEC 60894, IEC 61000-4-12

2.5 kV (peak value), 100 kHz polarity alternating, 1 MHz, 10 and 50 MHz, Ri = 200

EMC tests for interference emission; type tests

Standard

EN 50081-1 (Basic specification)

Radio interference voltage on lines 150 kHz to 30 MHz

only auxiliary supply

class B

IEC-CISPR 22

Interference field strength IEC-CISPR 22

30 to 1000 MHz class B

1 2 3 4 5 6 7 8 9 10 11

High-energy surge voltages

Impulse: 1.2/50 s

(SURGE),

IEC 61000-4-5 installation class III

Auxiliary supply

common mode: 2 kV; 12 , 9 F

differential mode:1 kV; 2 , 18 F

Measurement inputs, binary

common mode: 2 kV; 42 , 0.5 F

inputs

differential mode: 1 kV; 42 , 0.5 F

and relay outputs

10 V; 150 kHz to 80 MHz; 80 % AM;

Conducted RF, amplitude-

1 kHz

modulated IEC 61000-4-6, class III 30 A/m continuous; 300 A/m for

Magnetic field with power

3 s; 50 Hz

frequency

0.5 mT; 50 Hz

IEC 61000-4-8, class IV;

IEC 60255-6

12 13 14

Siemens SIP · Edition No. 8 12/13

Substation Automation/6MD66
Technical data

1 2 3 4 5 6 7 8 9 10 11 12 13 14

Mechanical dynamic tests

Vibration, shock stress and seismic vibration

During operation

Standards

IEC 60255-21 and IEC 60068-2

Vibration IEC 60255-21-1, class 2 IEC 60068-2-6

Sinusoidal 10 to 60 Hz: ± 0.075 mm amplitude; 60 to 150 Hz: 1 g acceleration Frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes

Shock IEC 60255-21-2, class 1 IEC 60068-2-27

Half-sinusoidal Acceleration 5 g, duration 11 ms, 3 shocks each in both directions of the 3 axes

Vibration during earthquake IEC 60255-21-2, class 1 IEC 60068-3-3

Sinusoidal 1 to 8 Hz: ± 4 mm amplitude (horizontal axis) 1 to 8 Hz: ± 2 mm amplitude (vertical axis) 8 to 35 Hz: 1 g acceleration (horizontal axis) 8 to 35 Hz: 0,5 g acceleration (vertical axis) Frequency sweep 1 octave/min 1 cycle in 3 orthogonal axes

During transport

Standards

IEC 60255-21 and IEC 60068-2

Vibration IEC 60255-21-1, class 2 IEC 60068-2-6

Sinusoidal 5 to 8 Hz: ±7.5 mm amplitude; 8 to 150 Hz: 2 g acceleration Frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes

Shock IEC 60255-21-2, class 1 IEC 60068-2-27

Half-sinusoidal Acceleration 15 g, duration 11 ms, 3 shocks each in both directions 3 axes

Continuous shock IEC 60255-21-2, class 1 IEC 60068-2-29

Half-sinusoidal Acceleration 10 g, duration 16 ms, 1000 shocks in both directions of the 3 axes

Climatic stress tests

Temperatures

Standards

IEC 60255-6

Recommended temperature during operation

-5 to +55 °C

25 to 131 °F

Temporary permissible temperature limit during operation (The legibility of the display may be impaired above 55 °C/131 °F)

-20 to +70 °C

-4 to 158 °F

Limit temperature during storage -25 to +55 °C

-13 to 131 °F

Limit temperature during transport Storage and transport with standard factory packaging

-25 to +70 °C

-13 to 158 °F

Humidity

Permissible humidity stress

Annual average 75 % relative

We recommend arranging the humidity; on 56 days a year up to

units in such a way that they are 93 % relative humidity; condensation

not exposed to direct sunlight or during operation is not permitted

pronounced temperature changes

that could cause condensation

Futher information can be found in the current manual at: www.siemens.com/siprotec

12/14 Siemens SIP · Edition No. 8

Substation Automation/6MD66
Selection and ordering data

Description 6MD66 high-voltage bay control unit
Processor module with power supply, input/output modules with a total of: Number of inputs and outputs 35 single-point indications, 22 1-pole single commands, 3 single commands to common potential, 1 live contact, 3 x current 4 x voltage via direct CT inputs, 2 measuring transducer inputs
Current transformer IN 1 A 1 A/150 % IN 1 A/200 % IN 5 A 5 A/150 % IN 5 A/200 % IN
Rated auxiliary voltage (power supply, indication voltage) DC 24 to 48 V, threshold binary input 19 V2) DC 60 V, threshold binary input 19 V2) DC 110 V, threshold binary input 88 V2) DC 220 to 250 V, threshold binary input 176 V2)
Unit version For panel flush mounting, with integr. local operation, HMI, plug-in terminal (2/3-pole AMP socket) For panel flush mounting, with integr. local operation, graphic display, keyboard, screw-type terminals (direct connec./ring-type cable lugs)
Region-specific default settings/function and language settings Region DE, 50Hz, language: German, changeable Region World, 50/60 Hz, language: English (GB), changeable Region US, ANSI, language: English (US), changeable Region World, 50/60 Hz, language: French, changeable Region World, 50/60 Hz, language: Spanish, changeable
System interface (on rear of unit, port B) No system interface IEC 60870-5-103 protocol, electrical RS485 IEC 60870-5-103 protocol, optical 820 nm, ST connector PROFIBUS DP Slave, electrical RS485 PROFIBUS DP Slave, 820 nm fiber, double ring, ST plugs PROFIBUS DP Slave, double electrical RS485 (second module on port D) IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector IEC 61850, 100 Mbit Ethernet, optical, double, LC connector
Function interface (on rear of unit, port C andD) No function interface DIGSI 4, electrical RS232, port C DIGSI 4, electrical RS485, port C DIGSI 4, optical 820 nm, ST connector, port D With RS485 interface for inter-relay communication, port C and DIGSI 4 With RS485 interface for inter-relay communication, port C and DIGSI 4, with optical 820 nm, ST connector, port D

Order No.

Order code

6MD662 - -0 -

see next page

1 2 3 5 6 7
2 3 4 5
D
E
A B C D E
0 2 3 9 9 9 9 9
0 1 2 3 4
5

L 0A L 0 B L 1A L 0 R L 0 S

1 2 3 4 5 6 7 8 9 10 11 12 13

1) The binary input thresholds can be selected in two stages by means of jumpers.

15
Siemens SIP · Edition No. 8 12/15

Substation Automation/6MD66
Selection and ordering data

Description

6MD66 high-voltage bay control unit

Measured-value processing

Full measured-value processing and display

No measured-value processing and no display Synchronization

With synchronization

Without synchronization

Protection function

Without protection functions

With auto-reclosure (AR)

With circuit-breaker failure protection With auto-reclosure and circuit-breaker failure protection

With fault recording

15
12/16 Siemens SIP · Edition No. 8

Order No.

Order code

6MD662 - -0 -

A F

0 1 2 3 4

Substation Automation/6MD66
Selection and ordering data

Description 6MD66 high-voltage bay control unit
Processor module with power supply, input/output modules with a total of: Number of inputs and outputs 50 single-point indications, 32 1-pole single commands, 3 single commands to common potential, 1 live contact, 3 x current, 4 x voltage via direct CT inputs 2 measuring transducer inputs 3 65 single-point indications, 42 1-pole single commands, 3 single commands to common potential, 1 live contact, 3 x current, 4 x voltage via direct CT inputs 2 measuring transducer inputs
Current transformer IN 1 A 1 A / 150 % IN 1 A / 200 % IN 5 A 5 A / 150 % IN 5 A / 200 % IN (for 6MD664)
Rated auxiliary voltage (power supply, indication voltage) DC 24 to 48 V, threshold binary input 19 V1) DC 60 V, threshold binary input 19 V1) DC 110 V, threshold binary input 88 V1) DC 220 to 250 V, threshold binary input 176 V1)
Unit version For panel surface mounting, detached operator panel, for mounting in low-voltage case, screw-type terminals (direct connec./ring-type cable lugs) For panel flush mounting, with integr. local operation, graphic display, keyboard, screw-type terminals (direct connec./ring-type cable lugs) For panel surface mounting, w /o operator unit, for mounting in low-voltage case, screw-type terminals (direct connec./ring-type cable lugs)
Region-specific default settings/function and language settings Region DE, 50 Hz, language: German, changeable Region World, 50/60 Hz, language: English (GB), changeable Region US, ANSI, language: English (US), changeable Region World, 50/60 Hz, language: French, changeable Region World, 50/60 Hz, language: Spanish, changeable
System interface (on rear of unit, port B) No system interface IEC 60870-5-103 protocol, electrical RS485 IEC 60870-5-103 protocol, optical 820 nm, ST connector PROFIBUS DP Slave, electrical RS485 PROFIBUS DP Slave, optical 820 nm, double ring, ST connector PROFIBUS DP Slave, double electrical RS485 (second module on port D) PROFIBUS DP Slave, double optical double ring ST (second module on port D) IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector IEC 61850, 100 Mbit Ethernet, optical, double, LC connector

Order No.

Order code

6MD66 - -0 -

see next page

2
3

3
4

1 2

2 3 4 5
C
E
F
A B C D E
0 2 3 9 9 9 9 9 9

L 0A

L 0 B
12 L 1 A
L 1 B

L 0 R

L 0 S

1) The binary input thresholds can be selected in two stages by means of jumpers.

15
Siemens SIP · Edition No. 8 12/17

Substation Automation/6MD66
Selection and ordering data

Description

6MD66 high-voltage bay control unit

Function interface (on rear of unit, port C and D)

No function interface

DIGSI 4, electrical RS232, port C

DIGSI 4, electrical RS485, port C

DIGSI 4, optical 820 nm, ST connector, port D1)

With RS485 interface for inter-relay communication, port C and DIGSI 4

With RS485 interface for inter-relay communication, port C and DIGSI 4, with optical 820 nm, ST connector, port D1)

Measured-value processing

Full measured-value processing and display

No measured-value processing and no display2)

Synchronization

With synchronization

Without synchronization Protection function

Without protection functions

With auto-reclosure (AR) incl. fault recording

With circuit-breaker failure protection (BF) incl. fault recording

With auto-reclosure (AR) and circuit-breaker failure protection (BF) incl. fault recording

Fault recording

1) Not for double PROFIBUS DP (position 11 = 9-L1A or 9-L1B).

2) Only for position 16 = 0 (without protection functions).

15
12/18 Siemens SIP · Edition No. 8

Order No. 6MD66 - -0
0 1 2 3 4
5
A F
A F
0 1 2 3 4

Bay unit 6MD662

Substation Automation/6MD66
Connection diagrams
1

Fig. 12/19 Module 1, indications, commands

Fig. 12/20 Module 2, indications, commands

Fig. 12/21 Module 4, measuring values commands

12 13

15
Siemens SIP · Edition No. 8 12/19

Substation Automation/6MD66
Connection diagrams

Bay unit 6MD662

Fig. 12/22 CPU, C-CPU 2

For unit 6MD662*-****1-0AA0 and

6MD662*-****2-0AA0

(DIGSI interface, electrical,

system interface optical or electrical)

or
8

Fig. 12/23 CPU, C-CPU 2 For unit 6MD662*-****3-0AA0 (DIGSI interface, optical, system interface optical or electrical)

12 13

Fig. 12/24 CPU, C-CPU 2 For unit 6MD662*-****4-0AA0 (Inter-relay communication interface electrical, system interface optical or electrical)

Fig. 12/25 C PU, C-CPU 2 For unit 6MD662*-****5-0AA0 (DIGSI interface, optical, Inter-relay communication interface electrical, system interface optical or electrical)

15
12/20 Siemens SIP · Edition No. 8

Bay unit 6MD664
Fig. 12/26 Module 1, indications, commands
Fig. 12/28 Module 4, indications, commands

Substation Automation/6MD66
Connection diagrams

Fig. 12/30 Module 2,

Fig. 12/27 Module 3,

indications, commands

Fig. 12/29 Module 5, measuring values, commands

12 13

15
Siemens SIP · Edition No. 8 12/21

Substation Automation/6MD66
Connection diagrams

Bay unit 6MD664

or or

Fig. 12/31 CPU, C-CPU 2

For unit 6MD664*-****1-0AA0

and 6MD664*-****2-0AA0

(DIGSI interface electric,

system interface optical optical or electric)

or
8

Fig. 12/32 CPU, C-CPU 2 For unit 6MD664*-****3-0AA0 (DIGSI interface optical, system interface optical optical or electric)

12 13 14

Fig. 12/33 CPU, C-CPU 2 For unit 6MD664*-****4-0AA0 (Inter-relay communication interface electric, system interface optical or electric)

Fig. 12/34 C PU, C-CPU 2 For unit 6MD664*-****5-0AA0 (DIGSI interface optical, (Inter-relay communication electric, system interface optical or electric)

15
12/22 Siemens SIP · Edition No. 8

Appendix

Relay characteristics Dimension drawings Assignment for products Order No. index Training

Page
13/2 13/7 13/19 13/20 13/21

Appendix
Relay characteristics

Inverse-time characteristics of TOC relays

IEC 60255-3 Normal Very

Extremely Long

ANSI/IEEE Inverse Short

Long

Definite Moderately Very

Extremely

inverse inverse inverse inverse

inverse inverse

Fig.

13/1

13/2

13/3

13/4

13/5

13/6

13/7

13/8

13/9

13/11 13/13

Relay

7SD5

7SD610

7SJ61

7SJ62

7SJ64

7UM62

7UT612 7UT613

7UT63

13/2 Siemens SIP · Edition No. 8.1

Inverse-time overcurrent protection characteristics according to IEC 60255 and BS142.

Appendix
Relay characteristics

Fig. 13/1 Inverse

( ) t =

0.14
0.02

I Ip -1

Fig. 13/2 Very inverse

1.35

( ) t =

Fig. 13/3 Extremely inverse
I = current t = tripping time Ip = pickup setting Tp = time multiplier setting

( ) t =

80
2

I Ip -1

Fig. 13/4 Long inverse

120

( ) t =

I Ip

Siemens SIP · Edition No. 8 13/3

Appendix
Relay characteristics

Inverse-time overcurrent protection characteristics

according to ANSI (IEEE) C37.112

6
7
Fig. 13/5 Inverse
8

8.9341

t = M 2.0938

+ 0.17966 -1

Fig. 13/6 Short inverse

Fig. 13/7 Long inverse

t = 5M.61-431

+ 2.18592 TD

t = tripping time in seconds M = current in multiples of pickup setting (I/Ip) range 0.1 to 4 TD = time dial

13/4 Siemens SIP · Edition No. 8

Fig. 13/8 Definite inverse

0.2663

t = M 1.2969

+ 0.03393 -1

0.4797 M 1.5625 -

0.21359

Inverse-time overcurrent protection characteristics according to ANSI (IEEE) C37.112

Appendix
Relay characteristics

Fig. 13/9 Moderately inverse

0.0103 M 0.02 -

0.0228

Fig. 13/10 Reset moderately inverse

treset

0.97 M2

TD -1

3.922 M2 -1

+ 0.0982

Fig. 13/11 Very inverse
t = tripping time in seconds M = current in multiples of pickup setting (I/Ip) range 0.1 to 4 TD = time dial

Fig. 13/12 Reset very inverse

treset

4.32 M2

TD -1

Siemens SIP · Edition No. 8 13/5

Appendix
Relay characteristics, pinout of communication port

Inverse-time overcurrent protection characteristics

according to ANSI (IEEE) C37.112

5.64 M2 -1

0.0243

Fig. 13/13 Extremely inverse

t = tripping time in seconds

M = current in multiples of pickup setting (I/Ip) range 0.1 to 4

TD = time dial

9 Pinout of communication port

Fig. 13/14 Reset extremely inverse

10 11

Pin no.

PC interface at front

Port A: Time synchronization

Port B: System interface

RS232

RS485

IEC 60870- IEC 60870-5-10

5-103

RS485 PROFIBUS DP Slave

RS485 Modbus, DNP 3.0

treset

5.82 M2

TD -1

Port C/D Rear service interface or protection data interface
RS232 RS485

12 13 15

P24 input 24 V Shield (with shield ends electrically connected)

R x D

P5 input 5 V

R x D

T x D

common return T x D

A/A' (RxD/TxD-N) B/B' (RxD/TxD-P)

T x D

CNTR-A (TTL)

RTS (TTL level)

GND

Shield

GND

C/C' (GND)

GND1

GND

+ 5 V voltage supply VCC1

(max. Load < 100 mA)

RTS

P12 input 12 V RTS

RTS

CTS

B/B' (RxD/TxD-P) A/A' (RxD/TxD-N)

CTS

Shield

*) Pin 7 also can carry the RS232 RTS signal to an RS485 interface. Pin 7 must therefore not be connected

A C (GND)
(RTS RS232 used) B

13/6 Siemens SIP · Edition No. 8

Appendix
Dimension drawings, reference table

Relay
6MD66 7SA522 7SA61
7SA63 7SA64 7SD5 7SD600 7SD610 7SJ61 7SJ62 7SJ64 7SJ66 7SS522 central unit 7SS523 bay unit 7SS525 7UM62 7UT6 7VE61 7VE63 7VK610/7VK611 7VU683

Flush/cubicle-mounting version

Page

Fig.

13/12

13/22

13/10, 13/12

13/19, 13/22

13/9, 13/10, 13/11, 13/18, 13/19, 13/20, 13/22 13/12

13/9, 13/10, 13/12 13/18, 13/19, 13/22

13/10, 13/12

13/19, 13/22

13/8

13/15

13/9

13/18

13/9

13/18

13/9

13/18

13/9, 13/10, 13/12 13/18, 13/19, 13/22

13/15, 13/16

13/25, 13/26

13/18

13/29

13/17

13/27

13/18

13/29

13/10, 13/12

13/19, 13/22

13/9, 13/10, 13/12 13/18, 13/19, 13/22

13/9

13/18

13/10

13/19

13/9, 13/10

13/18, 13/19

13/12

13/22

Surface-mounting version

Page

Fig.

13/13

13/23

13/13

13/23

13/11, 13/13

13/21, 13/23

13/11, 13/13
13/13 13/8, 13/9 13/11 13/11 13/11 13/11, 13/13 13/18 13/17
13/13 13/11, 13/13 13/11 13/13 13/11, 13/13 -

13/21, 13/23 13/23 13/16, 13/17 13/21 13/21 13/21 13/21, 13/23 13/29 13/27 13/23 13/21, 13/22 13/21 13/23 13/21, 13/23 -

Detached HMI Page Fig.

13/14 13/24

13/14 13/14 -

13/24 13/24 -

13
Siemens SIP · Edition No. 8_Update 2020 13/7

Appendix
Dimension drawings in mm/inch
Dimension drawings for ¹/ × 19" housing (7XP20)
1

Side view

View from the rear

Panel cutout

Fig. 13/15 Housing for panel flush mounting/cubicle mounting, terminals at rear (¹/ × 19")
6

Front view

Side view

Fig. 13/16 Housing for surface mounting, terminals at top and bottom (¹/ × 19")

13/8 Siemens SIP · Edition No. 8

Dimension drawings for ¹/ × 19" housing (7XP20)

Appendix
Dimension drawings in mm/inch

Front view

Side view

Fig. 13/17 Housing for panel surface mounting, terminals on the side (¹/ × 19")

Dimension drawings for SIPROTEC 4 x 19" housing (7XP20)

Side view

Rear view 7SA610, 7SD61, 7SJ64

Fig. 13/18 Housing for panel flush mounting/cubicle mounting ( × 19")

Rear view 7SJ61, 7SJ62, 7UT612, 7UM611

Panel cutout

Siemens SIP · Edition No. 8 13/9

Appendix
Dimension drawings in mm/inch

Dimension drawings for SIPROTEC 4

½ × 19" flush-mounting housings (7XP20)

5
Side view 1
6

Side view 2

Rear view 1 7SA61/63, 7UM621, 7UM623, 7SJ64

Rear view 2 7SJ63, 7UM612, 6MD63

Fig. 13/19 ½ × 19" flush-mounting housing

Rear view 3 7SA522, 7SD52/53

Panel cutout
Rear view 4 7UT613

13/10 Siemens SIP · Edition No. 8

Dimension drawings for SIPROTEC 4 ²/ × 19" flush-mounting housings (7XP20)

Appendix
Dimension drawings in mm/inch

Sied view

Rear view

Fig. 13/20 ²/×19" flush-mounting housing for 7SA613

Panel cutout

Rear view

Panel cutout

Front view

Sied view

Fig. 13/21 ×19" surface-mounting housing, terminals at top and bottom

13
Siemens SIP · Edition No. 8 13/11

Appendix
Dimension drawings in mm/inch

Dimension drawings for SIPROTEC 4

× 19" flush-mounting housings (7XP20)

4
Side view 1
5

Side view 2

9 10

Rear view 2 7SJ63, 6MD63

Rear view 3 7SA522, 7SD52/53

Fig. 13/22 × 19" flush-mounting housing 13/12 Siemens SIP · Edition No. 8

Panel cutout
* Terminals M and L additionally for 7UT635 and 7SJ647 only ** Terminals H and G not for 7SJ645 and 7SJ647 Rear view 1 7SA6, 7UM622, 7SJ64, 7UT633, 7UT635
Rear view 4 7VU683

Dimension drawings for SIPROTEC 4 ½ and × 19" surface-mounting housing (7XP20)

Appendix
Dimension drawings in mm/inch

Front view ½ × 19" surface-mounting, terminals at top and bottom housing 7XP20

Side view

Front view x 19" surface-mounting housing 7XP20 (without sloped FO case)
Fig. 13/23 ½ and × 19" surface-mounting housing

13
Siemens SIP · Edition No. 8 13/13

Appendix
Dimension drawings in mm/inch

Dimension drawings for SIPROTEC 4

½ and × 19" housings with detached operator panel

5
Detached operator panel (side view)
6

Rear view

Fig. 13/24 Housing with detached or no operator panel 13/14 Siemens SIP · Edition No. 8

Panel cutout

Appendix
Dimension drawings in mm/inch

Fig. 13/25 Dimensional Drawing of a 7SJ66 for Panel Flush and Cubicle Mounting (Housing Size ½)

Siemens SIP · Edition No. 8 13/15

Appendix
Dimension drawings in mm/inch
1 2 3 4 5 6 7 8 9 10 11 12 13 15
Fig. 13/26 Dimensional Drawing of a 7SJ66 for Panel Flush and Cubicle Mounting (Housing Size ) 13/16 Siemens SIP · Edition No. 8

Appendix
Dimension drawings in mm/inch

Front view

Side view

Fig. 13/27 7SS523 bay unit in 7XP2040-2 housing for panel flush mounting/cubicle mounting

Panel cutout

Front view

Side view

Fig. 13/28 7SS523 bay unit in 7XP2040-1 housing for panel surface mounting

View from below

Siemens SIP · Edition No. 8 13/17

Appendix
Dimension drawings in mm/inch

Front view

Side view

Rear view

Panel cutout

Fig. 13/29 7SS525 busbar and breaker failure protection unit for panel flush mounting/cubicle mounting with housing for wall mounting

Front view

Fig. 13/30 7SS522 central unit in SIPAC subrack

Top view

13/18 Siemens SIP · Edition No. 8

Products applied until now 7RP72

Function Frequency relay

7SD24 7SD510/511 7SD512
7SA500 7SA501 7SA502 7SA510 7SA511 7SA513
7SJ41 7SJ50 7SJ510 7SJ511 7SJ512 7SJ531 7SJ600, 7SJ601, 7SJ602
7SK52

Line differential relay Line differential relay via FO Line differential relay via FO
Distance protection Distance protection Distance protection Distance protection Distance protection Distance protection
Overcurrent relay Overcurrent relay Overcurrent relay Overcurrent relay Overcurrent relay Overcurrent relay Overcurrent relay
Motor protection

Recommended new products 7RW80 (SIPROTEC Compact)
7SD600 7SD610 7SD5
7SA6, 7SA522 7SA6, 7SA522 7SA6, 7SA522 7SA6, 7SA522 7SA6, 7SA522 7SA6, 7SA522
7SR45 (Reyrolle) 7SJ80 7SJ61 7SJ61 7SJ62 7SJ63 7SJ80
7SK80 (SIPROTEC Compact)

7UT512 7UT513 7UM51
7SS51
7SS13 7SS60 7RW600 7VH80/83, 7VH60

Transformer differential relay Transformer differential relay Machine protection

7UT612 7UT613/7UT63 7UM61/62

Busbar protection

7SS52

Busbar protection

7SS85

Busbar protection

7SS85

Voltage and frequency protection 7RW80

High-impedance diff. protection 7SR23 (Reyrolle)

7SN60 7SV512 7VK512
7XV72
7XS50

Transient ground-fault relay Breaker failure relay Auto-reclosure and synchronism check relay Test switch
DIGSI operating program

SIPROTEC 5 7VK61 7VK61
7XV75
7XS54

Appendix
Assignment for products
13

Siemens SIP · Edition No. 8 13/19

Appendix
Order No. index

1 2 3 4 5 6 7 8 9 10 11 12

Order No. 3PP1326 3PP1336 4NC5225 6MD66 7SA522 7SA61 7SA63 7SA64 7SD5 7SD610 7SJ61 7SJ62 7SJ64 7SJ66 7SS52 7UM62 7UT612 7UT613 7UT63 7VE6 7VK61 7VU683 7XS5401 7XS5402 7XS5403 7XS5407 7XS5408 7XS5410 7XS5411 7XS5416 7XS5460 7XS5461 7XS5490 7XT3300 7XT3400 7XT7100 7XV5100

Page 11/50 11/21, 11/50 11/50 12/5 6/59 6/23 6/24 6/25 7/47 7/20 5/17 5/43 5/58 5/73 9/13 11/3 8/35 8/37 8/39 11/33 10/15 11/53 3/4 3/4 3/4 3/4 3/4 3/8 3/8 3/8 3/4 3/6 3/4 11/50 11/50 11/50 5/20, 5/48, 5/77

13/20 Siemens SIP · Edition No. 8_Update 2020

Equipment reliability and availability are essential for all owners and users. At the same time, maintenance costs need to be kept to a minimum. The liberalization of energy markets presents new challenges to all; maintaining and enhancing competitive strength are among today's most important business goals. Investment in technical plants and human resources enables these goals to be realized. Innovations in the technical field confront the users with the need of establishing, maintaining and extending their qualification and know-how. Our training programs are tailored to meet your specific needs. With our know-how, we can help you to keep ahead.
Our training centers offer training programs comprising an extensive range of courses covering all the important aspects of numerical protective relaying. Choosing our courses will simplify your planning and ensure you of high-quality professional instruction at a reasonable cost. It is also possible to arrange training on your own premises thereby reducing costs for group participation. We will jointly plan a complete training program that matches your business goals and your particular working context.
Each course and the corresponding training documents are available in many languages. On the Internet at www.siemens.com/power-academy you will find our complete training program with details of contents, dates, costs and contacts.

Appendix
Training

13
Siemens SIP · Edition No. 8 13/21

Legal notice

Indication of conformity

This product complies with the directive of the Council of the European Communities on the approximation of the laws of the Member

States relating to electromagnetic compatibility (EMC Council Directive 2004/108/EC) and concerning electrical equipment for use within specified voltage limits (Low-voltage Directive 2006/95/EC).

document, or utilization and communication of the content are not permitted, unless authorized in writing. All rights, including rights created by patent grant or registration of a utility model or a design, are reserved.

This conformity has been established by means of tests con-

Registered trademarks

ducted by Siemens AG in accordance of the Council Directive in agreement with the generic standards EN 61000-6-2 and

EN 61000-6-4 for the EMC directives, and with the standard

EN 60255-5 for the low-voltage directive.

SIPROTEC®, DIGSI®, SIGUARD®,SIMEAS®, and SICAM® are registered trademarks of Siemens AG. Any unauthorized use is illegal. All other designations in this document can be trademarks whose use by third parties for their own purposes can infringe

The product is conforming to the international standards of the series IEC 60255 and the German regulation of DIN 57435

the rights of the owner.

part 303 (VDE 0435 part 303). Further standards are ANSI/IEEE

C37.90.0 and C37.90.1.

The device has been designed and produced for industrial use.

Disclaimer of liability

The content of this document has been compiled for information

purposes only. Although Siemens AG has made best efforts to

keep the document as precise and up-to-date as possible, Sie-

mens AG shall not assume any liability for defects and damage

which result through use of the information contained herein.

This content does not form part of a contract or of business

relations; nor does it change these. All obligations of

Siemens AG are stated in the relevant contractual agreements.

Siemens AG reserves the right to revise this document from time to time.

Document version: 08 / 8.1 Release status: 09.2020
9

13/22 Siemens SIP · Edition No. 8

Published by Siemens AG 2017 Energy Management Division Digital Grid Automation Products Humboldtstr. 59 90459 Nuremberg, germany
www.siemens.com/protection
For more information, please contact our Customer Support Center. Tel.: +49 180 524 7000 Fax: +49 180 524 2471 (Charges depending on provider) E-mail: support.energy@siemens.com

© 2016 Siemens. Subject to changes and errors. The information given in this document only contains general descriptions and/or performance features which may not always specifically reflect those described, or which may undergo modification in the course of further development of the products. The requested performance features are binding only when they are expressly agreed upon in the concluded contract.
Article No. IC1000-K4400-A101-A8 Not printed, only pdf KG 0317

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This product includes software developed by the OpenSSL Project for use in the OpenSSL Toolkit (http://www.openssl.org/). This product includes cryptographic software written by Eric Young (eay@cryptsoft.com). This product includes software written by Tim Hudson (tjh@cryptsoft.com). This product includes software developed by Bodo Moeller.
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