SIPROTEC Compact 7SD80, 7SJ80, 7SJ81, 7SK80, 7SK81, 7RW80

Transcription

www.siemens.com/protection
SIPROTEC Compact
7SD80, 7SJ80, 7SJ81, 7SK80, 7SK81,
7RW80, 7SC80
Catalog SIP 3.01 · Edition 3
Answers for infrastructure and cities.
Overview of Documentation
SIPROTEC
Compact
Catalog
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Selection
Guide
SIPROTEC and
Reyrolle
SIPROTEC 5
Devices
Catalog
Protection,
Automation
and Monitoring
5H\UROOH
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SIPROTEC 4
Catalog
- SIPROTEC easy
- SIPROTEC
600 Series
- Communication
- Accessories
Reyrolle
Catalog 1) 2)
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Fig. 1/1 Overview of Siemens protection catalogs
SIPROTEC Compact catalog
The catalog describes the features of the SIPROTEC Compact
series and presents the available devices and their application possibilities.
Selection guide
The selection guide offers an overview of the device series of
the Siemens protection devices, and a device selection table.
SIPROTEC 5 catalog
The system catalog describes the features of the SIPROTEC 5
system. The SIPROTEC 5 device catalogs describe devicespecific features such as scope of functions, hardware and
application.
SIPROTEC 4, SIPROTEC series 600, SIPROTEC easy,
communication and accessories
This catalog describes the features of the device series
SIPROTEC 4, SIPROTEC series 600 and SIPROTEC easy, as
well as their devices. In further chapters, the accessories of
the complete SIPRROTEC family for communication,
auxiliary relays and test equipment are described.
Reyrolle Katalog
This catalog gives an overvoew of the Reyrolle devices and
features.
Contents
SIPROTEC Compact
7SD80, 7SJ80, 7SJ81,
7SK80, 7SK81, 7RW80,
7SC80
Catalog SIP 3.01 · Edition 3
Introduction
Page
Editorial
Overview of all SIPROTEC device series
1/4
1/5 to 1/10
11
2/1 to 2/16
22
SIPROTEC Compact
Selection Table, System features
Operating programs
Products
Line Differential Protection SIPROTEC 7SD80
Invalid: Catalog SIP 3.01 · Edition 2
3/1 to 3/22
33
4/1 to 4/30
44
www.siemens.com/siprotec
Overcurrent Protection SIPROTEC 7SJ80
for Low-Power Current Transformer Applications
55
5/1 to 5/22
Generator and Motor Protection SIPROTEC 7SK80
66
6/1 to 6/28
for Low-Power Current Transformer Applications
77
7/1 to 7/26
Voltage and Frequency Protection SIPROTEC 7RW80
8/1 to 8/16
88
9/1 to 9/32
99
Feeder Protection SIPROTEC 7SC80
Attachment
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).
Ordering examples and accessories
10/3
Selection and ordering data
10/4
Dimension drawings
10/5
Legal notice
10/7
10
SIPROTEC Compact · SIEMENS SIP 3.01 · Edition 3 1/3
Introduction
Editorial
2
3
4
5
The SIPROTEC Compact series has been especially conceived
for the requirements of the medium-voltage and industrial
sector, but it can of course also be used for other applications
such as high-voltage switchgear, for example.
The outstanding feature of the SIPROTEC Compact series
is the compact design offering, at the same time, a high
functional density and user friendliness. In the development
of the SIPROTEC Compact series we have integrated our
experience from more than 100 years of protection systems,
the proven functions of SIPROTEC 4, and many customer
suggestions.
The Compact series fits perfectly into the SIPROTEC concept,
and can be combined with other devices of this system as
required.
With SIPROTEC we are offering you an open and future-proof
system family to solve the requirements of modern power
supply systems.
LSP3.01-0001.eps
1
We are pleased to have the opportunity to introduce our new
SIPROTEC Compact catalog to you.
Fig. 1/1 SIPROTEC Compact front
At the beginning, please orientate yourself by means of a
short overview of the complete SIPROTEC family, and then
discover the system features of the SIPROTEC Compact series.
Please convince yourself of the performance of SIPROTEC
Compact series, and develop the possible solutions for your
requirements.
SIPROTEC – safe, reliable and efficient.
6
Yours sincerely,
Ingo Erkens
8
LSP3.01-0002.eps
Municipal_utilities.tif
7
General Manager
Infrastructure & Cities Sector
Smart Grid Division
Energy Automation
Fig. 1/2 Application in medium voltage
9
10
1/4 SIPROTEC Compact · SIEMENS SIP 3.01 · Edition 3
Introduction
SIPROTEC device series
Solutions for today‘s and future power supply systems –
for more than 100 years
1
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.
2
As the innovation driver and trendsetter in the field of
protection systems for more than 100 years, Siemens helps
system operators 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. 1/5). The first application went into operation
in Würzburg, Germany, in 1977. Consistent integration of
protection and control functions for all SIPROTEC devices
was the 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 communication standard into operation. In the
meantime we have delivered more than 300,000 devices
with IEC 61850 included.
LSP3.01-0003.eps
SIPROTEC protection relays from Siemens can be consistently used throughout all applications in medium and high
voltage. With SIPROTEC, operators 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.
3
4
Fig. 1/3 SIPROTEC family
How can system operators benefit from this experience?
• Proven and complete applications
5
• Easy integration into your system
• Highest quality of hardware and software
• Excellent operator friendliness of devices and tools
• Easy data exchange between applications
6
• Extraordinary consistency between product and
system-engineering
• Reduced complexity by easy operation
• Siemens as a reliable, worldwide operating partner.
7
8
LSP3.01-0004-en.eps
9
Fig. 1/4 SIPROTEC – Pioneer over generations
10
Introduction
3
4
5
6
7
Thanks to the high modularity of hardware and software,
the functionality and hardware of the devices can be
tailored to the requested application and adjusted to the
continuously changing requirements throughout the entire
life cycle.
Besides 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.
Fig. 1/5 SIPROTEC 5 – modular hardware
• 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
• Clear and easy-to-use of devices and software thanks to
user-friendly design
• Increase of reliability and quality of the engineering
process
LSP3.01-0014.eps
2
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 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.
LSP3.01-0013.eps
1
SIPROTEC 5 – the new benchmark for protection,
automation and monitoring of transmission grids
• High safety by consistent implementation of Safety and
Security
• Powerful communication components guarantee safe and
effective solutions
• Full compatibility between IEC 61850 Editions 1 and 2
8
9
• Integrated switch for low-cost and redundant optical and
electrical Ethernet rings
Fig. 1/6 SIPROTEC 5 – modular process connection
• 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.
LSP3.01-0012.eps
10
Fig. 1/7 Application in a high-voltage power system
Introduction
SIPROTEC Compact –
Maximum protection – minimum space
1
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
1/6 x 19“ housing. The devices can be used as main protection in medium-voltage applications or as back-up protection in high-voltage systems.
LSP3.01-0007-en.eps
2
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.
4
Fig. 1/8 SIPROTEC Compact
• 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)
5
• 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
LSP3.01-0008.eps
• 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
Ethernet rings
3
6
7
8
Fig. 1/9 SIPROTEC Compact – rear view
• 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
9
• Adjustable to the protection requirements by means of
“flexible protection functions”
7SC80 mit HMI.png
• Comfortable engineering and evaluation via DIGSI 4.
Fig. 1/10 Feeder Protection SIPROTEC 7SC80 with HMI
10
Introduction
2
3
4
5
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.
LSP3.01-0010.eps
1
SIPROTEC 4 – the proven, reliable and future-proof
protection for all applications
Fig. 1/11 SIPROTEC 4
• 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
6
• Targeted and easy operation of devices and software
thanks to user-friendly design
7
8
LSP2174-afp.tif
• 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
Ethernet rings
highest availability.
Fig. 1/12 SIPROTEC 4 – rear view
9
LSP3.01-0011.eps
10
Fig. 1/13 SIPROTEC 4 application in power stations
Introduction
SIPROTEC easy
SIPROTEC easy are CT power supplied, numerical overcurrent
protection relays, which can be used as line and transformer
protection (back-up protection) in electrical power supply
systems with single-ended supply. They offer overcurrent
protection and overcurrent protection functions according
to IEC and ANSI. The comfortable operation via DIP switch is
self-explanatory and simple.
1
2
• Two-stage time-overcurrent protection
LSP3.01-0005.eps
• Saving the auxiliary power supply by operation via integrated current transformer supply
• Cost-efficient due to the use of instrument transformers
with low ratings
• Tripping via pulse output (DC 24 V / 0.1 Ws) or tripping
relay output
• Simple, self-explanatory parameterization and operation
via DIP switch directly at the device
4
• Easy installation due to compact assembly on DIN rail.
SIPROTEC Compact (series 600)
3
Fig. 1/14 SIPROTEC easy
5
The devices of the SIPROTEC Compact series (series 600)
are compact, numerical protection devices for application
in medium-voltage or industrial power supply systems. The
corresponding device types are available for the different
applications such as time-overcurrent protection, line differential protection, transient ground-fault relay or busbar
protection.
6
• Space-saving due to compact design
• Reliable process connections by means of solid terminal
blocks
LSP3.01-0006.eps
• Effective fault evaluation by means of integrated fault
recording and SIGRA 4
• Communication interface
• Operable and evaluable via DIGSI 4
7
8
• Different device types available for directional and nondirectional applications.
Fig. 1/15 SIPROTEC Compact (series 600)
9
10
Introduction
1
2
3
4
5
6
7
8
9
10
Protection Systems
SIPROTEC Compact
Protection Systems – SIPROTEC Compact
1
2
3
Seite
SIPROTEC Compact selection table
2/3
SIPROTEC Compact system features
2/4
Operation2/6
Construction and hardware
2/7
Control and automation functions
2/8
Operating programs DIGSI 4 and SIGRA 4
2/9
Communication2/12
4
5
6
7
8
9
10
Voltage and
frequency
protection
Feeder
protection
7SJ81
7SK80
7SK81
7RW80
7SC80
– not available
1) in preparation
C
C
C
C
C
C
–
–
–
–
–
–
–
–
–
–
–
V
C
C
1)
–
V
–
–
–
–
–
–
–
–
–
–
–
–
V
V
V
–
–
–
V
C
V
C
C
C
C
V
C
C
C
V
C
C
C
C
C
V
V
V
V
V
V
C
V
C
C
C
C
V
C
C
C
V
Generator
and motor
protection
7SJ80
C
Line
differential
protection
7SD80
C basic
V optional
Overcurrent
and feeder
protection
SIPROTEC Compact selection table
1
SIPROTEC Compact
ANSI
Siemens Funktion (de)
Protection functions for 3-pole tripping
Protection functions for 1-pole tripping
14
Locked rotor protection
FL
Fault locator
24
Overexcitation protection
25
Synchrocheck, synchronizing function
27
Undervoltage protection
27Q
Undervoltage-controlled reactive power protection
32
Directional power supervision
37
Undercurrent protection, underpower
38
Temperature supervision
46
Unbalanced-load protection
46
Negative-sequence system overcurrent protection
47
Phase-sequence-voltage supervision
48
Starting-time supervision
49
Thermal overload protection
50/50N
Definite time-overcurrent protection
50Ns
Sensitive ground-current protection
Intermittent ground-fault protection
50L
Load-jam protection
50BF
Circuit-breaker failure protection
51C
Cold load pickup
51/51N
Inverse time-overcurrent protection
51V
Voltage dependent overcurrent protection
55
Power factor
59
Overvoltage protection
59N
Overvoltage protection, zero-sequence system
59R, 27R
Rate-of-voltage-change protection
60FL
Measuring-voltage failure detection
66
Restart inhibit
67
Directional time-overcurrent protection, phase
67N
Dir.time-overcurrent protection for ground-faults
Dir. sensitive ground-fault detection for systems
67Ns
with resonant or isolated neutral
67Ns
Directional intermittent ground fault protection
74TC
Trip-circuit supervision
79
Automatic reclosing
81
Frequency protection
81R
Rate-of-frequency-change protection
Vector-jump protection
81LR
Load restoration
85
Teleprotection
86
Lockout
87
Differential protection
87N
Differential ground-fault protection
Broken-wire detection for differential protection
Weitere Funktionen
Measured values
Switching-statistic counters
Logic editor
Inrush-current detection
External trip initiation
Control
Fault recording of analog and binary signals
Monitoring and supervision
Protection interface, serial
No. Setting groups
Changeover of setting group
Circuit breaker test
Tabelle 2/1 SIPROTEC Compact relay selection table
Abk.
3-pole
1-pole
I> + V<
FL
V/f
Sync
V<
Q>, V>
P<>, Q<>
I<, P<
θ>
I2>
I2>, I2/I1>
LA, LB, LC
I2start
θ, I2t
I>
INs>
Iie>
I>L
CBFP
V
–
–
–
–
–
–
–
–
C
C
–
–
–
C
I 2t
I>, IP ∠ (V,I)
IN>, INP ∠ (V,I)
INs ∠ (V,I)
Iie dir>
TCS
AR
f<, f>
df/dt
∆φU>
LR
ΔI
ΔIN
–
–
C
C
V
C
C
V
–
–
C
C
V
C
C
C
V
–
–
–
V
C
C
C
V
V
V
V
V
V
–
–
–
V
V
V
V
V
V
C
V
V
V
V
V
V
–
–
–
–
IP, INP
t=f(I)+V<
cos j
V>
V0>
dV/dt
V
V
V
V
C
C
–
–
V
V
–
–
–
C
V
V
V
–
–
C
C
C
C
C
C
C
C
C
C
C
C
C
C
4
C
C
C
C
C
–
V
V
V
–
V
–
C
V
V
V
–
C
C
C
C
–
V
V
V
–
V
C
–
–
V
V
V
C
V
V
V
V
C
–
–
–
–
–
–
C
–
–
–
–
–
–
–
–
–
–
–
C
C
C
–
–
–
–
–
V
–
V
V
–
V
C
4
–
C
C
C
–
–
C
C
C
V
V
V
V
V
V
–
V
V
V
–
–
–
C
C
C
V
V
V
–
–
–
V
V
–
–
–
–
–
–
–
–
–
C
C
V
V
–
–
–
–
C
C
C
C
C
C
–
–
–
–
–
–
–
–
–
–
C
–
–
–
–
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
C
–
4
–
4
–
4
–
4
–
4
–
4
C
C
C
C
C
C
–
–
–
–
–
–
–
3
–
C
C
V
V
V
V
2
5
6
7
8
9
–
–
10
1
Field devices in energy distribution systems and in industrial
applications must cover the most varying tasks, and yet be
adjustable easily and at short notice. These tasks comprise,
for example:
• Protection of different operational equipment such as
lines, cables, motors and busbars
2
• Decoupling and disconnecting of parts of the power
supply system
• Load shedding and load restoration
• Voltage and frequency protection
• Local or remote control of circuit-breakers
3
• Acquisition and recording of measured values and events
• Communication with neighboring devices or the control
center.
Fig. 2/1 shows exemplary how the most different tasks can
be easily and safely solved with the matching
SIPROTEC Compact devices.
Operation
During the development of SIPROTEC Compact, special value
was placed not only on a powerful functionality, but also on
simple and intuitive operation by the operating personnel.
Freely assignable LEDs and a six-line display guarantee an
unambiguous and clear indication of the process states.
In conjunction with up to 9 function keys and the control
keys for the operational equipment, the operating personnel
can react quickly and safely to every situation. This ensures
a high operational reliability even under stress situations,
thus reducing the training effort considerably.
4
5
Infeed
6
7SJ80
SIEMENS
52
Voltage/frequency protection
Load shedding
Load restoration
MV-Substation
52
7SD80
SIEMENS
8
52
Busbar protection via
reverse interlocking
possible
9
10
SIEMENS
7SJ80
SIEMENS
52
7SJ80
SIEMENS
7RW80
SIEMENS
SIEMENS
7SC80
52
7SK80
SIEMENS
52
7SJ80
SIEMENS
M
G
7SD80
52
7SK80
SIEMENS
52
52
Cable
Generation
Fig. 2/1 Fields of application in a typical MV system
Transformer
Feeder
Motor
Bus Coupler
1_17_Visio_Compact.pdf
7
7RW80
Backup transformer
protection
Busbar protection via
reverse interlocking
Load Balancing
The Feeder Automation device SIPROTEC 7SC80 is designed
for decentralized as well as for centralized feeder automation applications. This solution allows various flexible high
speed applications like
Balance the load within a feeder by moving the disconnection.
FLISR (Fault Location, Isolation, and Service Restoration)
Detect and locate a fault in the feeder, isolate the faulty
section and set the healthy portions of the feeder back into
service
Activation of individual line sections
Isolate a dedicated section of a feeder for maintenance
without affecting other sections. Fig. 2/2 shows an example
of a typical ring main application with overhead lines and 5
sections. Every section is protected and automated by the
SIPROTEC 7SC80 Feeder Protection.
1
2
Source transfer
Detect and isolate a faulty source and set the de-energised
sections of the feeder back into service
3
4
5
Substation
Substation
A
B
52
52
50/50N
OR
50/50N
OR
Start fault isolation
Current-jump detection
6
7
8
Communication network
52
52
50/50N
OR
50/50N
OR
OR
9
50/50N
52
10
Fig. 2/2 Fields of application with feeder protection SIPROTEC 7SC80
Operation
Local operation
1
2
All operations and information can be executed
via an integrated user interface:
2 operation LEDs
In an illuminated 6-line LC display, process and
device information can be indicated as text in
different lists.
4 navigation keys
3
8 freely programmable LEDs serve for indication
of process or device information. The LEDs can
be labeled user-specifically. The LED reset key
resets the LEDs.
4
6
7
Numerical operation keys
LSP2899.eps
5
9 freely configurable function keys
support the user in performing frequent
operations quickly and comfortably.
with open board
USB user interface (type B) for modern
and fast communication with the
operating software DIGSI.
Keys “O” and “I” for direct control of
operational equipment.
8
LSP2900.eps
9
10
Battery cover accessible from outside.
with closed board and
open battery cover
Connection techniques and housing with
many advantages
Fig. 2/5 7SK80, 7SJ80, 7SD80
rear view
LSP3.01-0034.eps
All binary inputs are independent and
the pick-up thresholds are settable using
software settings (3 stages). The relay
current transformer taps (1 A / 5 A) are new
software settings. Up to 9 function keys can
be programmed for predefined menu entries, switching sequences, etc. The assigned
function of the function keys can be shown
in the display of the relay.
Fig. 2/6 Voltage terminal block
LSP3.01-0008.eps
Pluggable current and voltage terminals
allow for pre-wiring and simplify the
exchange of devices in the case of support.
CT shorting is done in the removable current
terminal block. It is thus not possible to opencircuit a secondary current transformer.
1
LSP3.01-0033.eps
The relay housing is 1/6 of a 19" rack and
makes replacement of predecessors model
very easy. The height is 244 mm (9.61").
2
3
Fig. 2/7 Current terminal block
With overcurrent protection SIPROTEC 7SJ81
there is also a device for low-power current
transformer applications.
4
5
Wmax = 9.5 mm
Ring-type lugs
d1 = 5.0 mm
Wire size
2
2.0 – 5.2 mm (AWG 14 – 10)
Current terminals – single cables
Cable cross-section
2.0 – 5.2 mm2 (AWG 14 – 10)
Conductor sleeve with
plastic sleeve
L = 10 mm (0.39 in) or
L = 12 mm (0.47 in)
Stripping length
(when used without
conductor sleeve)
15 mm (0.59 in)
Only solid copper wires may
be used.
Fig. 2/8 7SJ81, 7SK81 rear view
LSP3.01-0016.eps
Connection
LSP3.01-0015.eps
Current terminals – ring-type lugs
Fig. 2/9 7RW80 rear view
Voltage terminals – single cables
Cable cross-section
0.5 – 2.0 mm2 (AWG 20 – 14)
Conductor sleeve with
plastic sleeve
L = 10 mm (0.39 in) or
L = 12 mm (0.47 in)
Stripping length
(when used without
conductor sleeve)
12 mm (0.347 in)
Only solid copper wires may
be used.
6
7
8
9
w
SIP C-0002.ai
d1
Table 2/2 Wiring specifications for process connection
LSP2901.eps
Fig. 2/11 Ring-type lug
10
Fig. 2/10 Front view,
surface-mounting housing
Control and automation functions
1
2
Control
Assignment of feedback to command
In addition to the protection functions, SIPROTEC Compact
units also support all control and monitoring functions
that are required for operating medium-voltage or highvoltage substations. The status of primary equipment or
auxiliary devices can be obtained from auxiliary contacts
and communicated to the unit 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 positions of the circuit-breaker or switching devices
and transformer taps are acquired through feedback. These
indication inputs are logically assigned to the corresponding
command outputs. The unit can therefore distinguish whether the indication change is a result of switching operation
or whether it is an undesired spontaneous change of state.
The switchgear or circuit-breaker can be controlled via:
–– integrated operator panel
3
–– binary inputs
–– substation control and protection system
–– DIGSI 4.
4
5
6
7
8
9
Chatter disable
The chatter disable feature evaluates whether, in a set period of time, the number of status changes of indication input
exceeds a specified number. 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
With integrated logic, the user can create, through a graphic
interface (CFC), specific functions for the automation of a
switchgear or a substation. Functions are activated using
function keys, a binary input or through the communication
interface.
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 an indication delay, there is a delay for a preset time. The
information is passed on only if the indication voltage is still
present after this time.
Switching authority
Indication derivation
Switching authority is determined by set parameters or
through communications to the relay. Each switching
operation and switch-position change will be noted in the
operational log. Command source, switching device, cause
(spontaneous change or command) and result of
a switching operation will be stored.
User-definable indications can be derived from individual
or a group of indications. These grouped indications are of
great value to the user that need to minimize the number of
indications sent to the system interface.
Automation / user-defined logic
Command processing
All functionalities of the command processing are available.
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 alarms
by combination with existing information.
10
DIGSI 4, an operating software for
all SIPROTEC protection devices
The PC operating program DIGSI 4 is the user interface
to the SIPROTEC devices, regardless of their version. It is
designed with a modern, intuitive user interface.
With DIGSI 4, SIPROTEC devices are configured and evaluated – it is the tailored program for industrial and energy
distribution systems.
1
2
3
4
5
6
7
8
9
Fig. 2/12 DIGSI 4 operating program
10
Simple protection setting
From the numerous protection
functions it is possible to easily select
only those which are really required
(see Fig. 2/13). This increases the
clearness of the other menus.
1
2
Device setting with primary or
secondary values
Assignment matrix
The DIGSI 4 matrix shows the user
the complete configuration of the
device at a glance (Fig. 2/14). For
example, the assignment of the LEDs,
the binary inputs and the output
relays is displayed in one image. With
one click, the assignment can be
changed.
4
5
Fig. 2/13 DIGSI 4, main menu, selection of protection functions
LSP3.01-0018.eps
3
LSP3.01-0017.eps
The settings can be entered and
displayed as primary or secondary
values. Switching over between
primary and secondary values is
done with one mouse click in the tool
bar (see Fig. 2/13).
IEC 61850 system configurator
The IEC 61850 system configurator,
which is started out of the system
manager, is used to determine the
IEC 61850 network structure as well as
the extent of data exchange between
the participants of a IEC 61850
station. To do this, subnets are added
in the “network” working area – if
required –, available participants are
assigned to the subnets, and addressing is defined. The “assignment”
working area is used to link data
objects between the participants, e.g.,
the starting message of the V /inverse
time-overcurrent protection I > function of feeder 1, which is transferred
to the incoming supply in order to
prompt the reverse interlocking of the
V / inverse time-overcurrent protection
I >> function there (see Fig. 2/15).
7
8
9
Fig. 2/14 DIGSI 4, assignment matrix
System Configurator.tif
6
10
Fig. 2/15 DIGSI 4, IEC 61850 system configurator
CFC: Projecting the logic instead of
programming
1
With the CFC (continuous function
chart), it is possible to link and
derive information without software
knowledge by simply drawing technical
processes, interlocks and operating
sequences.
2
Logical elements such as AND, OR,
timers, etc., as well as limit value requests of measured values are available
(Fig. 2/16).
Special attention has been paid to
commissioning. All binary inputs and
outputs can be set and read out in
targeted way. Thus, a very simple
wiring test is possible. Messages can
be sent to the serial interface deliberately for test purposes.
3
LSP2324-afpen.tif
Commissioning
4
Fig. 2/16 CFC plan
SIGRA 4, powerful analysis of all
protection fault records
5
lt is of crucial importance after a line
fault that the fault is quickly and fully
analyzed so that the proper measures
can be immediately derived from the
evaluation of the cause. As a result,
the original line condition can be
quickly restored and the downtime
reduced to an absolute minimum. lt is
possible with SIGRA 4 to display records
from digital protection units and fault
recorders in various views and measure
them, as required, depending on the
relevant task.
6
LSP2330-afpen.tif
7
FASE and FAST: Convenient
engineering and test tool for Feeder
Automation Applications
FASE is a standalone engineering
Fig. 2/17 Typical time-signal representation
tool to create easy and flexible feeder
automation applications with 7SC80
feeder protection devices. By using
predefined standard or customized
S1
A P02 B
P01
DIGSI parameter set files, engineers can
use defined templates to create the MV
E
topology graphically via drag&drop.
FASE offers as well an editable table
with most relevant protection and
communication settings of all SIPROTEC
7SC80 devices at a glance.
Within FASE you can create flexible
sequences step by step for several
applications with the graphical user
interface.
S3
P07
F
P08 G
9
P03 C
P04
D
P05
S2
I
P11
S4
P06
P09
H
P10
10
J P12
S5
P13
K
P14
L
8
P15
P16
M
P17
S6
Bild 2/18 Fase configuration
Communication
1
2
Communication
System interface protocols (retrofittable)
As regards communication, the devices offer high flexibility
for the connection to industrial and energy automation
standards. The concept of the communication modules
running the protocols enables exchangeability and retrofittability. Thus, the devices can also be perfectly adjusted to a
changing communication infrastructure in the future, e.g.,
when Ethernet networks will be increasingly used in the
utilities sector in the years to come.
• IEC 61850
The ethernet-based protocol IEC 61850 is established as
a worldwide standard for protection and systems control.
SIPROTEC devices work as IEC 61850 servers and, via
the protocol, they can exchange extensive data with up
to 6 clients (e.g. SICAM PAS or SICAM TM1703) which
are defined in logical nodes in the IEC 61850 Standard
for protection and systems control functions. Static and
dynamic reports are supported. Additionally, fault records
can be transmitted which are stored in the binary Comtrade
format in the device. Switching commands can be executed
in the controlling direction. Data can be transmitted within
few milliseconds between devices via GOOSE messages of
the IEC 61850. This efficient intercommunication between
devices replaces the former parallel wiring through communication connections via the ethernet network.
USB interface
There is a USB interface on the front of the relay. All the
relay functions can be parameterized on PC by using DIGSIprograms. Commissioning tools and fault analysis are built
into the DIGSI program and are used through this interface.
3
Interfaces
A number of communication modules suitable for various
applications can be fitted at the bottom of the housing.
The modules can be easily replaced by the user. The interface modules support the following applications:
4
• System/service 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 the IEC 61850 protocol and
can also be accessed using DIGSI. Alternatively, up to 2 external temperature detection devices with max. 12 metering
sensors can be connected to the system/service interface.
5
6
• Ethernet interface
The Ethernet interface has been designed for quick access to
several protection devices via DIGSI. In the case of the motor
protection 7SK80, it is possible to connect max. 2 external
temperature detection devices with max. 12 metering
sensors to the Ethernet interface. As for the line differential
protection, the optical interface is located at this interface.
7
8
9
10
IEC 61850 is supported in Edition 1 and Edition 2 and the
devices are certified independently in compliance with
IEC 61850 Part 10.
The time synchronization can be made redundantly via
two SNTP timers which are integrated in the IEC 61850
engineering.
In addition to the IEC 61850 protocol, further protocols are
available on the ethernet module. They can be activated and
deactivated through DIGSI 4 so that safety requirements are
fulfilled. The devices can be accessed completely with DIGSI 4
via the ethernet network with the ethernet module. Diagnostic pages of the module can be accessed via a browser,
e.g. for supporting the commissioning. The device can be
integrated into a network monitoring system via SNMP V2
which allows monitoring permanently the behavior of the
device in the network. The network redundancy protocols
RSTP and HSR which are integrated on the ethernet module
permit the construction of economical ring structures.
Interruption-free redundancy can be achieved via parallel
networks with PRP.
Communication
• IEC 60870-5-103
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.
Optionally, a redundant IEC 60870-5-103 module is
available. This redundant module allows to read and change
individual parameters.
• IEC 60870-5-104
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
IEC 60870-5-104 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 IEC 60870-5-104. Moreover, GOOSE messages of
IEC 61850 can be exchanged between devices.
• PROFIBUS-DP
PROFIBUS-DP is a widespread protocol in industrial automation. Through PROFIBUS-DP, SIPROTEC units make their
information available to a SIMATIC controller or receive commands from a central SIMATIC controller or PLC. Measured
values can also be transferred to a PLC master.
• MODBUS RTU
This simple, serial protocol is mainly used in industry and
by power utilities, and is supported by a number of relay
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.
• 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.
zation is performed via the DNPi client or SNTP. The device
can also be integrated into a network monitoring system via
the SNMP V2 protocol.
1
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.
2
• 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 from 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.
3
4
5
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.
6
• Redundancy protocols for Ethernet (RSTP, PRP and HSR
7
SIPROTEC Compact supports the redundancy protocols RSTP,
PRP and HSR. These protocols 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.
8
9
• 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 synchroni-
10
Communication
System solutions
1
IEC 60870
2
Substation
control system
Due to the standardized interfaces, SIPROTEC devices can
also be integrated into systems from other manufacturers, or
into a SIMATIC system. Electrical RS485 or optical interfaces
are available. Optoelectronic converters enable the optimal
selection of transmission physics. Thus, cubicle-internal wiring with the RS485 bus, as well as interference-free optical
connection to the master can be implemented at low cost.
3
IEC 61850
An interoperable system solution is offered for IEC 61850
together with SICAM. Via the 100 MBit/s Ethernet bus, the
devices are connected electrically or optically to the station
PC with SICAM. The interface is standardized, thus enabling
the direct connection of devices from other manufacturers to
the Ethernet bus.
4
5
With IEC 61850, the devices can also be installed in systems
of other manufacturers.
SIPROTEC 4
SIPROTEC 4
SIPROTEC Compact
SIP-0003a-en.ai
Devices with IEC 60870-5-103 interfaces can be connected
to SICAM in parallel via the RS485 bus or radially via optical
fiber. Via this interface, the system is open for connection of
devices from other manufacturers.
Fig. 2/19 IEC 60870-5-103: Radial fiber-optic connection
DIGSI
Option:
SICAM
PAS
Control
center
switch
6
SIP-0004a-en.ai
7
8
Fig. 2/20 Bus structure for station bus with Ethernet and IEC 61850, fiber-optic ring
9
LSP3.01-0021.eps
10
Fig. 2/21 Optical Ethernet communication module for IEC 61850
Communication
System solution (continued)
Operating and
monitoring
Telecontrol interface to
system control centers
(e.g. IEC60870-5-104)
1
Time syncronization
DCF77, GPS
Substation
controller
Max. 12
temperature sensor
e.g.
2
RJ45
Station bus
RTD box
1)
1)
1)
3
1)
4
7SK80
7SK80
7SK80
7SK80
DIGSI 4
Telecontrol
via modem
DIGSI
LSA4868b-en.ai
DIGSI
5
DIGSI 4
(Local for IBS)
Fig. 2/22 System solution/communication
s
Max. 12
temperature sensor
RJ45 cable
Y cable
7KE6000-8GD00-0BA2
RJ45 cable
Y cable
7KE6000-8GD00-0BA2
7SK80 only
RTD box
RJ45 cable
Switch
Port B
7XV5673
SICAM I/O Unit
Switch
7XV5673
SICAM I/O Unit
RJ45 cable
RTD-Unit
6
2_23_Visio-SICAM-IO-Unit-02-20120731-us.pdf
To substation
controller
Port A
7
8
7XV5662
Fig. 2/24 Connection of 2 SICAM I/O Units and 1 RTD-box using Y cable
(maximum 2 SICAM I/O-Units lockable)
Port A
RJ45 1)
9
Port A
7SK80
DIGSI
LSA4825b-en.ai
RJ45 cable
DIGSI 4
(Local for IBS)
Fig. 2/23 Connection of an RTD box to 7SK80
using Ethernet interface
1)On SIPROTEC 7SK80, the RJ45 interface at port A
can be used for connection of a thermo-box. On
SIPROTEC 7SD80, port A is reserved for the optical
interface.
Y cable
7KE6000-8GD00-0BA2
RJ45 cable
7SJ80 or
7SK80
Switch
7XV5673
Switch
7XV5673
SICAM I/O Unit
SICAM I/O Unit
Fig. 2/25
Connection of 2 SICAM I/O Units on port A using Y cable
(maximum 2 SICAM I/O-Units lockable)
2_24_Visio-SICAM-IO-Unit-01-20120731-us.pdf
s
10
1
2
3
4
5
6
7
8
9
10
Line Differential Protection 7SD80
SIPROTEC Compact
Page
1
2
3
Description
3/3
Function overview
3/4
Applications
3/5
Application sheets
3/6
Application examples
3/9
3/12
Connection diagrams
3/14
Connection examples
3/20
4
5
6
7
8
9
10
You will find a detailed overview of the technical data
(extract of the manual) under:
http://www.siemens.com/siprotec
Description
Description
The line differential protection SIPROTEC 7SD80 has been
conceived for selective line protection of power cables and
overhead lines up to 24km for all kind of starpoint configurations.
2
3_2_LSP3.01-0008.eps
The implemented phase comparison algorithm is a fast and
stable method for line protection in industry and distribution
grids. The protection interface communication is carried
out directly without external equipment over copper wires,
optical fibers or both in redundancy. The wide scope of non
directional and directional functions can be applied miscellaneously as emergency functions as well as backup functions.
For instance the 7SD80 enables simplified and cost saving
concepts for meshed grids and busbar protection by means of
reverse interlocking. Fast and selective tripping is guaranteed
even if the communication fails between the relays. The scope
of functions includes protection functions as well as functions
for control and monitoring. The interoperable connectivity to
substation control systems is give by standard protocols like
IEC61850. The general concept of redundance for protection
and its communication gets completed by Ethernet redundancy protocols (PRP, HSR, RSTP) and thus increases the total
system availability. Integrated functions for commissioning
help and easy settings lead to short commissioning times.
1
3
4
Fig. 3/1 SIPROTEC 7SD80 front view
5
Protection interface communication
3_1_LSP3.01-0030.eps
Data exchange takes place via integrated interface in two-wire and fiber-optic respectively. By parallel use of both options
communication redundancy is realised. Communication via
the protection interface can further be used to send an intertripping command to the circuit-breaker at the opposite end,
and to exchange at the same time up to 16 freely assignable
binary signals between the SIPROTEC 7SD80 devices.
6
7
Highlights
• Pluggable current and voltage terminals
• Binary input thresholds settable using DIGSI (3 stages)
• Secondary current transformer values (1 A / 5 A) settable
using DIGSI
Fig. 3/2 SIPROTEC 7SD80 rear view
8
• 9 programmable function keys
• 6-line display
SIPROTEC 7SD80-specific features
• Buffer battery exchangeable from the front
• Short commissioning times by an easy parameterization
and integrated commissioning help for protection and
communication
• USB front port
• 2 additional communication ports
Ethernet rings
• Relay-to-relay communication through Ethernet with
IEC 61850 GOOSE
• Millisecond-accurate time synchronization through
Ethernet with SNTP.
9
• Integrated interfaces for exchanging differential protection
data (fiber-optic up to 24 km / 15 miles and/or two-wire
copper cables up to 20 km / 12 miles)
• Application for differential protection
• Integrated monitoring function of the protection interface,
both in the commissioning phase and in running operation
• Integrated non-directional and directional time-overcurrent
protection
• Transmission of a circuit-breaker intertripping signal and
16 further binary signals to the opposite end.
10
Function overview
1
2
Protection functions
IEC
ANSI No.
Differential protection, line
ΔI
87L
3I0 differential protection
Δ3I0
87N L
Ground-fault differential protection for systems with resonant or isolated neutral
ΔIEE
87Ns L
Definite time-overcurrent protection with delay for phase
I>, I>>, I>>>
50 TD (3 stages)
Definite time-overcurrent protection with delay for earth
IE>, IE>>, IE>>>
50N TD (3 stages)
Inverse time-overcurrent protection (phase)
IP
51
Inverse time-overcurrent protection (ground)
IEP
51N
LSVS
50BF
AKU
74TC
Comment
Optional
Inrush current detection
3
Lockout
86
Circuit-breaker intertripping scheme
85 DT
4
5
Undervoltage/overvoltage protection
V<, V>
27/59
Optional
Underfrequency/overfrequency protection
f<, f>
81 U/O
Optional
Directional time-overcurrent protection (phase)
I>, I>>, IP
67 (3 stages)
Optional
Directional time-overcurrent protection (ground)
IE>, IE>>, IPE
67N (3 stages)
Optional
Automatic reclosing
ARE
79
Flexible protection functions for current, voltage, power, cosϕ, frequency
Flex Funk
I 2t
Optional
Partly optional
49
Control functions
6
7
8
Table 3/1 Function overview
Control functions / programmable logic
Communication interface
• Commands (e.g. for the control of circuit-breakers, disconnect switches, grounding switches, etc.) through:
• System interface
–
–
–
–
keyboard
binary inputs
DIGSI 4
communication interface
• User-defined PLC logic with CFC (e.g. interlocking).
–
–
–
–
–
–
IEC 61850 Edition 1 and 2
IEC 60870-5-103
MODBUS RTU
DNP 3.0
PROFIBUS-DP
Ethernet redundancy protocols RSTP, PRP and HSR
• Service interface
Monitoring functions
9
• Operational measured values V, I, f
• Energy metering values Wp, Wq
• Circuit-breaker wear monitoring
• Minimum and maximum values
– USB front interface for DIGSI 4
– RS232/RS485 (instead of the system interface)
• Protection interface
– Fiber-optic connection and/or
– Two-wire connection.
• Trip circuit supervision
Hardware
• Fast measuring voltage failure “fuse-failure-monitor”
• 4 current transformers
• 8 oscillographic fault records.
• 0/3 voltage transformers
• 3/5/7 binary inputs (thresholds configurable using
software)
10
• 5/8 binary outputs (2 changeover)
• 1 life contact
• Pluggable current and voltage terminals.
Applications
The SIPROTEC 7SD80 is a numerical line differential
protection relay, which in addition to its main function, the
selective protection of overhead lines and cables, also covers
control and monitoring tasks.
Line protection
SIPROTEC 7SD80 devices are suitable as selective line protection for application in high-voltage and medium-voltage
systems of all types of neutral designs (solid, low-resistance
or high-resistance earthed, isolated or compensated).
Apart from the main protection function, the line differential
protection, SIPROTEC 7SD80 offers a lot of additional protection functions. These can be used in parallel as a backup
protection function, or as an emergency function if the main
protection function fails, and they complement the range of
functions of 7SD80 for application in transmission lines.
Control
The integrated control function permits control of disconnect
devices, grounding switches or circuit-breakers through
the integrated operator panel, binary inputs, DIGSI 4 or the
control or automation system (e.g. SICAM)
Operational measured values
Extensive measured values (e.g. I, V), metered values
(e.g.Wp,Wq) and limit values (e.g. for voltage, frequency)
provide improved system management as well as simplification by the commissioning
As for the operational measured values, a special focus was
placed on the measured values critical for differential protection. So, the attenuation values and the signal-to-noise ratio
of the communication connection, for example, are acquired
and indicated in addition to the measurement of the quality
of the telegram exchange per time unit.
Particular attention was paid to making the commissioning
of the differential protection easier and safer. In this context,
the amplitude and angle of the currents and of the voltages,
if applicable, are displayed additionally with reference to the
local measuring variable. In this way, a possible incorrect
connection (polarity reversal) of the current transformers can
be detected and eliminated early enough.
Operational indication
Monitoring of operation is ensured and documented by
storage of event logs, trip logs, fault records and statistics.
1
2
3
4
Programmable logic
5
The integrated logic characteristics (CFC) allow the user to
add own functions for automation of switchgear (e.g. interlocking) or switching sequence. The user can also generate
user-defined messages. This functionality can form the base
to create extremely flexible transfer schemes.
6
7
Busbar
Control/Remote Control
Commands/Feedbacks
52
74TC
86
Measurement and metered value
Threshold value
Mean value
I, V, Watt
Energy value
Vars, p, f
min/max-memory
Supervision functions
PDI-FO
opt. Budget
Rec. Power
V-Trans.monitor.
I/V-Symmetry
PDI-Cu
S/R-Ratio
Rec. Power
Fast Sum. I
8
Protection Data Interface
(PDI)
BERT
Rec.Power
S/N-Ratio
fiber-optic interface
(4 km MMF or 20 km SMF)
AND / OR
9
2-Wire-Copper interface
(SH-DSL to approx. 20 km)
87N L
87NsL
67
Main protection function
Inrush
Current Monitoring
50TD
67N
79
85 DT
DT
binTrans
FlexFunk
49
81U/O
27/59
directional emergency- and/or
backup protection function
51
50NTD
51N
50BF
non-directional emergency- and/or backup protection
function
Additional protection functions
3_3_Bild-001-us.pdf
87L
1) Not available if function package 'Q' (synchrocheck, ANSI 25) is selected.
Fig. 3/3 Function diagram
10
Application sheets
1
2
3
4
5
6
7
Differential protection (ANSI 87L, 87N L, 87Ns L)
The differential protection SIPROTEC 7SD80 consists of two
separately operating differential protection algorithms:
• Phase comparison protection (PCP)
• Earth-fault differential protection (EFD).
The phase comparison protection, PCP, offers a safe and
robust short-circuit protection for all types of neutral treatment. Of course, this is also valid for application in systems
with isolated or resonant-earthed neutral. Adaptation of
the phase comparison protection according to the neutral
treatment is done by setting parameters via DIGSI.
The earth-fault differential protection, EFD, operates with
two different algorithms, depending on the neutral treatment in the power system to be protected.
For application in solidly, low-resistance or high-resistance
earthed systems, the EFD analyzes the measured zero-sequence current. The fundamental wave of the zero-sequence
current is determined by filtering. The filtered zero-sequence
currents of the local side and the opposite side are added
and provide the zero-sequence differential current. The adaptive stabilizing facilitates the parameterization and assured
stability and selectivity.
For application in power systems with isolated or resonantearthed neutrals, the connection of voltages – at least of the
zero-sequence voltage – and the use of a sensitive earth-current transformer is required. From the zero-sequence current
and the voltage, the apparent power of the zero-sequence
system is calculated, and compared with the opposite end.
Depending on the direction of the power flow, an internal or
external earth fault is detected. This is only indicated, and
can be shut down immediately or with a set delay.
Circuit-breaker intertripping (ANSI 85 DT)
8
9
The 7SD80 devices have an integrated circuit-breaker intertripping function for tripping the circuit-breaker at the opposite end. The circuit-breaker intertripping can be activated
directly by the differential protection functions, but also
through binary signals of any other external or internal protection function. The circuit-breaker intertripping can be
combined with an integrated phase and/or zero-sequence
current threshold, which permits to trip the circuit-breaker
if there is a sufficiently high current.
Overcurrent protection, non-directional / directional
(ANSI 50, 50N, 51, 51N, 67, 67N)
This function is based on the phase-selective measurement
of the three phase currents and the earth current (4 instrument transformers).
10
In the SIPROTEC 7SD80, three definite time-overcurrent
protection stages are integrated for protection against phase
faults, as well as for protection against earth faults. The current
threshold and the delay time can be set for each stage. Furthermore, inverse time-overcurrent protection characteristics
can be added.
Each of the overcurrent protection stages can be set as emergency or backup protection independently of each other. This
enables the integration of the SIPROTEC 7SD80 in a simple
busbar protection concept by means of reverse interlocking.
When voltage transformers are connected, a directional
time-overcurrent protection emergency function can be
activated if the protection interface communication fails.
Available inverse-time characteristics
Characteristics acc. to
IEC 60255-3
ANSI / IEEE
Inverse


Short inverse
Long inverse


Moderately inverse


Very inverse


Extremely inverse


Tabelle 3/2 Available inverse-time characteristics
Inrush restraint
When the second harmonic is detected while energizing a
transformer inside or outside of the protection zone, pickup
of the differential protection stages or the overcurrent
protection stages can be suppressed.
Breaker failure protection (ANSI 50BF)
If a faulted portion of the electrical circuit is not disconnected
when a trip command is issued to a circuit-breaker, another
trip command can be initiated using the breaker failure protection which trips the circuit-breaker of an upstream feeder.
Breaker failure is detected if, after a trip command is issued
the current keeps on flowing into the faulted circuit. It is also
possible to make use of the circuit-breaker position contacts
for indication as opposed to the current flowing through the
circuit-breaker.
Through a binary input, an external protection device or monitoring equipment can be coupled into the signal processing
of the SIPROTEC 7SD80 to trip the local circuit-breaker.
Application sheets
Trip circuit supervision (ANSI 74TC)
Undervoltage protection (ANSI 27)
One or two binary inputs can be used for monitoring the
circuit-breaker trip coil including its incoming cables. An alarm
signal is generated whenever the circuit is interrupted.
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
conditions and a possible loss of stability. Proper operating
conditions of electrical machines are best evaluated with
the positive-sequence quantities. The protection function is
active over a wide frequency range (± 10 % rated frequency).
Even when falling below this frequency range the function
continues to work, however, with decreased accuracy. 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 singlephase connections are possible.
Flexible protection functions
SIP-0002.en.EPS.pdf
SIPROTEC 7SD80 enables the user to easily add up to 20
additional protective functions. Parameter definitions are
used to link standard protection logic with any chosen
characteristic quantity (measured or calculated quantity).
The standard logic consists of the usual protection elements
such as the pickup set point, the set delay time, the TRIP
command, a block function, etc. The mode of operation for
current, voltage, power and power factor quantities can be
three-phase or phase-selective. Almost all quantities can be
operated with ascending or descending pickup stages (e.g.
under and over voltage). All stages operate with protection
priority or speed.
dV/dt
SIP-0002.en.ai
Fig. 3/4 Flexible protection functions
Lockout (ANSI 86)
All binary output statuses can be memorized. The LED reset
key is used to reset the lockout state. The lockout state is also
stored in the event of supply voltage failure. Reclosure can
only occur after the lockout state is reset.
Thermal overload protection (ANSI 49)
To protect cables, an overload protection function with an
integrated warning/alarm element for temperature and
current can be used. The temperature is calculated using
a thermal homogeneous body model (per IEC 60255-8), it
considers the energy entering the equipment and the energy
losses. The calculated temperature is constantly adjusted
according to the calculated losses. The function considers
loading history and fluctuations in load.
1
2
3
Frequency protection (ANSI 81O/U)
Frequency protection can be used for overfrequency and underfrequency protection. Electric machines and parts of the
system are protected from unwanted frequency 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 (± 10 Hz rated frequency). There are four elements
(individually set as overfrequency, underfrequency or OFF)
and each element can be delayed separately. Blocking of the
frequency protection can be performed by activating a binary
input or by using an undervoltage element.
4
5
Customized functions (ANSI 32, 51V, 55 etc.)
6
Additional functions can be implemented using CFC or
flexible protection functions. Typical functions include
reverse power, voltage controlled overcurrent, phase angle
detection, and zero-sequence voltage detection.
7
Fast current monitoring
and further monitoring functions
SIPROTEC 7SD80 incorporates comprehensive monitoring
func-tions for hardware and software. Monitoring comprises
the measuring circuits, the analog-digital conversion, the
protection data communication connection the internal
supply voltages, the memories and the software sequence
(watchdog).
Overvoltage protection (ANSI 59)
8
9
10
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. Three-phase and single-phase connections are
possible.
Application sheets
Local measured values
Measured values of protection data communication
1
The r.m.s. values are calculated from the acquired current
and voltage along with the power factor as well as cos ϕ,
frequency, active and reactive power. The following functions are available for measured value processing:
Extensive measured values serve for the monitoring of
the quality and the availability of the used protection data
communication connections. For the fiber-optic interface,
the following measured values are available:
2
• Currents IL1, IL2, IL3, IN, IEE
• Voltages VL1, VL2, VL3, V12, V23, V31
• Sending and receiving power of the optical communication
module
• Symmetrical components I1, I2, 3I0; V1, V2, 3V0
• Power Watts, Vars, VA/P, Q, S (P, Q: total and phase
selective)
• Power factor cos ϕ (total and phase selective)
3
6
7
• Energy ± kWh, ± kVarh, forward and reverse power flow
For the two-wire interface, the following measured values
are available:
• Limit value monitoring.
Limit values can be monitored using programmable logic
in the CFC. Commands can be derived from this limit value
indication. With each measured value a limit value is
possible.
• Damping of the copper cable
• Signal-to-noise ratio of the signal received
• Telegrams sent per second, minute and hour
• Sum of correct and incorrect telegrams received per
second, minute and hour
• Availability of the protection interface.
Zero suppression:
Metered values
In a certain range of very low measured values, the value is
set to zero to suppress interference.
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 7SD80 can obtain and process metering pulses
through an indication input. The metered values can be displayed and passed on to a control center as an accumulated
value with reset. A distinction is made between forward,
reverse, active and reactive energy.
Measured values of the opposite end
Every two seconds, the currents and voltages of the other
end of the line are transmitted through the communication
connection, and indicated in relation to the locally measured
currents and voltages. The following measured values are
available:
• Amplitude of currents IL1, IL2, IL3
• Phase angle of currents ϕIL1, ϕIL2, ϕIL3
8
• Sum of correct and incorrect telegrams received per
second, minute and hour
• Availability of the protection interface.
• Mean operating temperature of the overload function
5
• Telegrams sent per second, minute and hour
• Frequency
• Operating hours counter
4
• Optical damping of the fiber-optic cable
• Amplitude of voltages VL1, VL2, VL3
• Phase angle of voltages ϕVL1, ϕVL2, ϕVL3.
9
10
Radial feeder
Infeed
52
I> 1.2 IN; TI> = 1.2 s
1
52
7SJ80
7SD80
2
˂,
I>
Here, using the line differential
protection SIPROTEC 7SD80 is a
simple remedy. This relay clears faults
between the substations selectively
and instantaneously, thus reducing
the maximum fault clearance time of
the radial feeder.
Station A
7SD80
˂,
Station A
52
Station A
Load
I> 1.2 IN; TI> = 0.9 s
52
I> 1.2 IN; TI> = 0.9 s
7SJ80
7SJ80
I>
Station B
52
Station B
Load
52
I>
Station C
Load
I> 1.2 IN; TI> = 0.3 s
52
7SJ80
7SJ80
7
I>
Station D
Load
I> 1.2 IN ; TI > = 0 s
52
Load
8
I> 1. 2 IN ; TI > = 0 s
7SJ80
7SJ80
I>
Load
6
Load
I> 1.2 IN; TI> = 0.3 s
I>
52
5
7SJ80
I>
Station D
Load
I> 1.2 IN; TI> = 0.6 s
7SJ80
52
4
I>
I> 1.2 IN; TI> = 0.6 s
Station C
3
Load
I>
Load
max. fault clearance time from power utility
Tripping time for overcurrent protection only
Tripping time when using differential protection
9
3_5_7SD80_Protection concept.tif
In the example shown, this is represented generally for the line between
the infeed and substation A.
Infeed
3_5_Bild-002-us.pdf
The protection of a radial feeder with
several substations via overcurrenttime protection leads to comparably
high shutdown times at the point of
infeed due to the necessary time grading. The stipulated fault clearance
time may therefore not be attainable.
Fig. 3/5 Protection concept to reduce the shutdown times at the
point of infeed of a radial feeder
10
Applications examples
Parallel feeder
As a difference to the alternative
concept of the direction comparison
protection, SIPROTEC 7SD80 does not
require voltage transformers.
2
Infeed
52
7SD80
In addition, the shorter fault clearance time prevents damage to the
generators at the opposite end.
4
7SD80
˂,
˂,
The communication connection
required in each case only leads to
instantaneous, strictly selective tripping when the differential protection
is used
3
52
7SD80
7SD80
˂,
˂,
Station A
52
52
7SJ80
7SJ80
I>
I>
G
5
Bild 3/6 Protection of parallel feeders via SIPROTEC 7SD80
6
7
8
9
10
3_6_Bild-003-us.pdf
Parallel feeders with bidirectional
power flow can be ideally protected
with the line differential protection
SIPROTEC 7SD80.
1
Ring feeder
Common alternative protection concepts are mostly based on the use of
directional time-overcurrent protection, which on the other hand also
requires voltage transformers in
the substations. An inverse grading
of these directional definite timeovercurrent protection devices, however, leads to long fault clearance
times. The use of the definite timeovercurrent relays as direction comparison protection requires – like
the differential protection – a communication connection between the
protection devices at the ends of the
corresponding ring segment, but this
does not reach the fault clearance
time of the differential protection.
The definite time-overcurrent protection integrated in SIPROTEC 7SD80
includes three stages, two thereof can
also be used as directional definite
time-overcurrent protection stages.
The operating mode of each stage is
settable. The stage can be activated
permanently, or only if the differential
protection function fails, e.g. if the
communication connection fails.
These definite-time stages allow
to configure an integrated backup
protection concept with the SIPROTEC
7SD80 relays in the ring-main panels.
Moreover, a busbar protection system
can also be implemented in the
substations by means of a reverse
interlocking.
Infeed
1
Infeed
52
52
52
7SD80
˂,
7SD80
>Z
Station A
˂,
2
˂,
>Z
Ring feeder
Station B
˂,
7SD80
7SD80
52
3
52
52
52
52
52
7SD80
7SJ80
7SJ80
7SD80
˂,
I>
I>
˂,
Load
Station C
˂,
4
Load
Station D
˂,
7SD80
5
7SD80
52
52
52
52
52
52
7SD80
7SJ80
7SJ80
7SD80
˂,
I>
I>
˂,
Load
Load
3_7_Bild-004-us.pdf
The line differential protection
SIPROTEC 7SD80 is ideally suited to
protect ring feeders. Faults on the
connection cables/lines of the ring
are cleared strictly selectively and
instantaneously. For this purpose,
connection of the SIPROTEC 7SD80
devices to a current transformer is
sufficient. For the main protection
function of the SIPROTEC 7SD80,
voltage transformers are not necessary. Even intermediate infeeds in the
substations of the ring are completely
covered by this protection concept.
6
7
Ring feeder
Bild 3/7 Protection concept for ring feeders via SIPROTEC 7SD80
8
9
10
Product description
Order No.
Short code
12345 6 7
1
7SD80
8 9 10 11 12 13 14 15 16 17 18 19
-
-
+
Housing 1/6 19”, binary inputs and outputs, 1 life contact
2
4 x I, 3 BI, 5 BO (Incl. 2 changeover / Form C), prot. data interface FO for
mono- (24 km) and multimode (4 km), LC-duplex connector
1
4 x I, 7 BI, 8 BO (Incl. 2 changeover / Form C), prot. data interface FO for
2
4 x I, 5 BI, 8 BO (Incl. 2 changeover / Form C), prot. data interface, 2 wires copper, twisted 3)
3
5
4 x I, 3 x V, 7 BI, 8 BO (Incl. 2 changeover / Form C), prot. data interface FO for
6
4 x I, 3 x V, 5 BI, 8 BO (Incl. 2 changeover/Form C), prot. data interface, 2 wires copper twisted 3)
continued
next page
3
4 x I, 3 x V, 3 BI, 5 BO (Incl. 2 changeover / Form C), prot. data interface FO for
7
Measuring inputs, default settings
4
Iph = 1 A / 5 A, IE = 1 A / 5 A
1
Iph = 1 A / 5 A, IEE (sensitive) = 0.001 to 1.6 A / 0.005 to 8 A
2
Rated auxiliary voltage
5
DC 24 V to 48 V
1
DC 60 V to 250 V; AC 115 V; AC 230 V
5
Unit version
Surface mounting housing, screw-type terminal
B
Flush mounting housing, screw-type terminal
E
Region-specific default- and language settings
6
Region DE, IEC, language German (Language selectable), standard face plate
A
Region World, IEC/ANSI, language English (Language selectable), standard face plate
B
Region US, ANSI, language US-English (Language selectable), US face plate
C
Port B (at bottom of device)
7
No port
0
IEC 60870-5-103 or DIGSI 4/modem or time sync. port, electrical RS232
1
IEC 60870-5-103 or DIGSI 4/modem or time sync. port, electrical RS485
2
IEC 60870-5-103 or DIGSI 4/modem time sync. port, optical 820 nm, ST connectors
3
Further protocols see supplement L
8
9
PROFIBUS DP slave, electrical RS485
9
L 0 A
PROFIBUS DP slave, optical, double ring, ST connector
9
L 0 B
MODBUS, electrical RS485
9
L 0 D
MODBUS, optical 820 nm, ST connector
9
L 0 E
DNP 3.0, electrical RS485
9
L 0 G
DNP 3.0, optical 820 nm, ST connector
9
L 0 H
IEC 60870-5-103, redundant, electrical RS485, RJ45 connector
9
L 0 P
IEC 61850, 100 Mbit Ethernet, 2 electrical ports, RJ45 connector
9
L 0 R
IEC 61850, 100 Mbit Ethernet, 2 FO ports, LC-duplex connector
9
L 0 S
Port A (at bottom of device)
No port 1)
0
Redundant FO protection data interface to the 2 wire copper interface
Protection data interface FO for mono- (24 km) and multimode (4 km), LC-duplex connector 2)3)
10
7
Measuring / fault recording
With fault recorder
1
With fault recorder, average values, min/max values
1) The FO interface is equipped,
if MLFB position 6 = 1, 2, 5 or 6
2) Only if MLFB position 6 = 3 or 7
3
3) By using 2-wire-protection interface a external isolating
transformer should be used
– PCM-transformer 6 kV orderno. C53207-A406-D195-1
– PCM-transformer 20 kV order no. 7XR9516
A detailed overview of the technical data (extract of the manual) you will find under: http://www.siemens.com/siprotec
ANSI No.
Variants
Order No.
Bestell-Nr.
Short code
12345 6 7
7SD80
8 9 10 11 12 13 14 15 16 17 18 19
-
Medium voltage differential protection device
Basic version (contained in all options)
87L/87N L
50 TD/51
50N TD/51N
49
74TC
50BF
86
85 DT
27/59
81 U/O
2
3
4
5
F B
Directional definite/inverse time-overcurrent protection, phase 3) ∠(V,I) I>, I>>, Ip
Directional definite/inverse time-overcurrent protection ground 3) ∠(V,I) IE>, IE>>, IEp
F C
Ground-fault differential protection for isolated/resonance-earthed networks 3) 4)
Basic version included
67
67N
87Ns L
1)
Line differential protection
(phase comparison and 3IO differential protection 1))
Inrush-current detection
Definite/inverse time-overcurrent protection phase I>, I>>, I>>>, Ip
Definite/inverse time-overcurrent protection ground IE>, IE>>, IE>>>, IEp
Trip circuit supervision
Lockout
Circuit-breaker intertripping function (trip of the remote circuit-breaker)
Parameter changeover (parameter group change)
Supervision functions
Circuit-breaker test
Control of circuit-breaker
Flexible protection function current, voltage 2),
cos ϕ 2), power 2), frequency 2)
Under-/Overvoltage protection 2) V<, V>
Under-/Overfrequency protection 2) f<, f>
87Ns L
1
+
F A
67
67N
-
6
F E
3)
Directional definite/inverse time-overcurrent protection, phase ∠(V,I) I>, I>>, Ip
Directional definite/inverse time-overcurrent protection, ground 3) ∠(V,I) IE>, IE>>, IEp
Ground-fault differential protection for isolated/resonance-earthed networks 3) 4)
7
Additional functions
Without
0
Transmission of 16 binary signals via the protection data interface
1
79
With automatic reclosure function (AR)
2
79
Transmission of 16 binary signals via the protection data interface and
With automatic reclosure function (AR)
3
8
9
10
1) MLFB position 7 = 1 required (Iph = 1 A / 5 A, IE = 1 A / 5 A)
2) Function available if MLFB position 6 = 5, 6 or 7 (voltage transformer inputs)
3) MLFB position 6 = 5, 6 or 7 required (voltage transformer inputs)
4) MLFB position 7 = 2 required (Iph = 1 A / 5 A, IEE (sensitive) = 0.001 to 1.6 A / 0.005 to 8 A)
Connection diagrams
1
Surface / flush-mounting housing
IA
F1
F2
F3
F4
F5
F6
F7
F8
C11
C10
C9
BO2
C14
C12
C13
BO3
E1
E2
E3
E4
E5
E6
IC
I N, INS
BO4
3
BO5
4
C3
C4
C5
C6
C7
C8
5
BI1
BI2
BI3
Life Contact
E10
E7
E8
=
(~)
Power Supply
=
6
+
-
C1
C2
Port B
e.g. System interface
3_8_Visio-kl-uebers-7sd80-1-100801-us.pdf
7
Port A
FO-Protection Data Interface
8
USB-DIGSI-Interface
Grounding on the case
Bild 3/8 Line differential protection SIPROTEC 7SD801
9
10
B
A
Interference Suppression
Capacitors at the Relay
Contacts, Ceramic, 2.2 nF,
250 V
2
IB
BO1
Connection diagrams
1
IA
F1
F2
F3
F4
F5
F6
F7
F8
IB
BO1
C11
C10
C9
BO2
C14
C12
C13
BO3
E1
E2
E3
E4
E5
E6
D9
D10
D11
D12
D13
D14
IC
I N, INS
BO4
BO5
BO6
BO7
C3
C4
C5
C6
C7
C8
BI1
D1
D2
D3
D4
D5
D6
D7
D8
BI4
BO8
BI2
BI3
Life Contact
3
4
E10
E7
E8
=
BI5
2
(~)
Power Supply
=
+
-
5
C1
C2
6
BI6
Port A
USB-DIGSI-Interface
B
A
7
250 V
BI7
Port B
8
9
10
Connection diagrams
1
IA
F1
F2
F3
F4
F5
F6
F7
F8
C11
C10
C9
BO2
C14
C12
C13
BO3
E1
E2
E3
E4
E5
E6
D9
D10
D11
D12
D13
D14
IC
I N, INS
BO4
3
BO5
BO6
4
BO7
C3
C4
C5
C6
C7
C8
5
BI1
BO8
BI2
BI3
D1
D2
D5
D7
D6
D8
Cu-Protection Data Interface
=
BI4
BI5
6
7
8
E10
E7
E8
Life Contact
(~)
Power Supply
=
+
C1
C2
-
Port B
Port A
USB-DIGSI-Interface
B
A
250 V
2
IB
BO1
The fiber-optic interface at port A is only available in connection with position 12 = 7
9
10
Connection diagrams
1
IA
F1
F2
F3
F4
F5
F6
F7
F8
IB
BO1
C1 1
C10
C9
BO2
C1 4
C12
C13
2
BO3
E1
E2
E3
E4
E5
E6
3
IC
I N, INS
BO4
E9 Q2
E11
E12
E13
E14
VA
VB
BO5
VC
C3
C4
C5
C6
C7
C8
4
BI1
BI2
BI3
=
+
C1
C2
-
Port B
Port A
USB-DIGSI-Interface
6
B
A
7
250 V
=
(~)
Power Supply
5
E10
E7
E8
Life Contact
8
9
10
Connection diagrams
1
IA
F1
F2
F3
F4
F5
F6
F7
F8
4
5
I N, INS
7
8
C14
C12
C13
BO3
E1
E2
E3
E4
E5
E6
D9
D10
D11
D12
D13
D14
BO4
VA
VB
BO5
VC
BO6
BO7
C3
C4
C5
C6
C7
C8
BI1
D1
D2
D3
D4
D5
D6
D7
D8
BI4
BO8
BI2
BI3
Life Contact
E10
E7
E8
=
BI5
(~)
Power Supply
=
BI7
-
C1
C2
Port B
Port A
USB-DIGSI-Interface
9
+
BI6
3_12 Visio-kl-uebers-7sd80-2-100801-us.pdf
6
BO2
IC
E9 Q2
E11
E12
E13
E14
3
C11
C10
C9
10
B
A
250 V
2
IB
BO1
Connection diagrams
1
IA
F1
F2
F3
F4
F5
F6
F7
F8
IB
BO1
C1 1
C10
C9
BO2
C1 4
C12
C13
BO3
E1
E2
E3
E4
E5
E6
D9
D10
D11
D12
D13
D14
IC
I N, INS
BO4
E9 Q2
E11
E12
E13
E14
VA
VB
BO5
VC
BO6
BO7
C3
C4
C5
C6
C7
C8
BI1
BO8
BI2
2
3
4
BI3
D1
D2
D5
D7
D6
D8
5
E10
E7
E8
Life Contact
Cu-Protection Data Interface
BI5
(~)
Power Supply
=
+
C1
C2
-
Port B
Port A
USB-DIGSI-Interface
6
B
A
7
250 V
=
BI4
8
The fiber-optic interface at port A is only available in connection with position 12 = 7
9
10
Connection examples
Current transformer connection
52
2
52
52
Surface-/Flush Mounting Housing
P2
S2
P1
S1
A
3
B
F1
IA
F2
F3
IB
F4
F5
IC
F6
F7
C
IN
F8
3_14_SIP C-0007-us.pdf
1
SIPROTEC
Fig. 3/14 Current transformer connections on three current transformers and neutral
current (earth current) (Holmgreen circuit); normal circuit suitable for all solidly
and impedance earthed systems (neutral towards line)
4
52
52
52
5
P2
S2
P1
6
S1
A
B
F1
IA
F2
F3
IB
F4
F5
IC
F6
F7
IN
F8
SIPROTEC
C
Fig. 3/15 Current transformer connections on three current transformers and neutral current (earth current) (Holmgreen circuit); normal circuit suitable
for all solidly and impedance earthed systems (neutral towards busbar)
8
52
52
52
F1
F3
9
F5
P2
S2
P1
S1
A
10
B
C
P2
S2
P1
S1
F8
IA
IB
IC
F2
F4
F6
IN
SIPROTEC
Fig. 3/16 Current transformer connections on three current transformers –
earth current of additional summation current transformer, preferably
for resonant-earthed and isolated systems.
F7
7
Connection examples
Voltage transformer connection
52
52
Surface-/Flush Mounting
Housing
52
A
E9
VA
E11
VB
B
E12
a
A
B
b
VC
E13
E14
SIPROTEC
C
1
3_17_Visio-anschl-u1e-u2e-u3e-abgang-20070129-us.pdf
A
B
C
2
3
Fig. 3/17 Example for connection type “V1E, V2E, V3E”, feeder-side voltage connection
4
A
B
C
52
Housing
52
A
B
E9
VA
E11
VB
E12
da
dn
E13
E14
VC
SIPROTEC
A
B
5
52
6
C
7
Fig. 3/18 Example for connection type “V0 connection”
8
9
10
1
2
3
4
5
6
7
8
9
10
Overcurrent Protection 7SJ80
SIPROTEC Compact
Page
1
2
3
4
Description
4/3
Function overview
4/4
Applications
4/5
Application sheets
4/6
4/12
4/18
Connection diagrams
4/21
Connection examples
4/27
Connection types
4/30
5
6
7
8
9
10
Description
Description
The SIPROTEC 7SJ80 relays can be used for line/feeder protection of high and medium-voltage networks with grounded,
low-resistance grounded, isolated or a compensated neutral
point. The relays have all the required functions to be applied
as a backup relay to a transformer differential relay.
1
The SIPROTEC 7SJ80 features “flexible protection functions”.
Up to 20 additional protection functions can be created by
the user.
2
Therefore protection of change for frequency or reverse
power protection can be realized, for example.
LSP3.01-0022.eps
The relay provides circuit-breaker control, further switching
devices and automation functions. The integrated programmable logic (CFC) allows the user to add own functions, e.g.
for the automation of switchgear (interlocking). The user is
also allowed to generate user-defined messages.
Highlights
3
4
using DIGSI
5
Fig. 4/1 SIPROTEC 7SJ80 front view, housing
• 6-line display
• USB front port
6
Ethernet rings
7
IEC 61850 GOOSE
LSP3.01-0008.eps
Ethernet with SNTP (over Port A or Port B)
• Number of binary inputs and inary outputs by connection
from up to two SICAM I/O-Units extendable.
8
9
Fig. 4/2 SIPROTEC 7SJ80 rear view
10
Function overview
1
2
IEC
ANSI No.
Definite and inverse time-overcurrent protection (phase/ground)
I>, Ip, INp
50, 50N; 51, 51N
Directional time-overcurrent protection phase
I>, I>>, I>>>, Ip
67
Directional time-overcurrent protection ground
IE>, IE>>, IE>>>, IEp
67N 1)
Directional sensitive ground fault protection
IEE>, IEE>>, IEEp
67Ns 1), 50Ns
V E, V 0>
59N 1)
High-impedance restricted ground-fault protection
87N
Inrush restraint
3
4
Trip-ciruit supervision
TCS
74TC
Undercurrent monitoring
I<, P>
37
Overload protection
ϑ>
49
V<, V>
27/59
Overfrequency/underfrequency protection
f<, f>
81O/U
CBFP
50BF
27Q
Undervoltage controlled reactive power protection
Q>/V<
Intermittent ground fault protection
Iie>
Iie dir>
Voltage dependent inverse-time overcurrent protection
5
6
7
67Ns 1)
51V
I 2>
46
LA, LB, LC
47
Synchrocheck
Sync
25
Automatic reclosing
AR
79
Fault locator
FL
FL 1)
Forward power supervision, reverse power protection
P<>, Q<>
32 1)
Power factor
cos ϕ
55 1)
df / dt
81R
dV/dt
27R, 59R
Lockout
86
8
9
10
Control functions/programmable logic
Communication interfaces
• Commands for the ctrl. of CB, disconnect switches
(isolators/isolating switches)
• Control through keyboard, binary inputs,
DIGSI 4 or SCADA system
– IEC 61850 Edition 1 and 2
– IEC 60870-5-103 and IEC 60870-5-104
– PROFIBUS-DP
– DNP 3.0
– MODBUS RTU
– DNP3 TCP
– PROFINET
– Ethernet redundancy protocols RSTP, PRP and HSR
• Ethernet interface for DIGSI 4 and extension up to two
SICAM I/O-Units 7XV5673
• USB front interface for DIGSI 4.
•
•
•
•
•
•
•
Operational measured values V, I, f
Energy metering values Wp, Wq
Circuit-breaker wear monitoring
Minimum and maximum values
Trip circuit supervision (74TC)
Fuse failure monitor
8 oscillographic fault records.
1) Not available if function package “Q” (synchrocheck, ANSI 25)
is selected.
Hardware
• 3/7/11 binary inputs (thresholds configurable using
software)
• 5/8 binary outputs (2 changeover/Form C contacts)
• 1 life contact
Applications
The SIPROTEC 7SJ80 perform control and monitoring
functions and therefore provide the user with a cost-effective
platform for power system management, that ensures
reliable supply of electrical power to the customers. The
ergonomic design makes control easy from the relay front
panel. A large, easy-to-read display was a key design factor.
Control
The SIPROTEC 7SJ80 units can be used for line protection of high
and medium-voltage networks with grounded, low-resistance
grounded, isolated or a compensated neutral point.
Event logs, trip logs, fault records and statistics documents are
stored in the relay to provide the user or operator with all the
key data required to operate modern substations.
Line protection
1
2
Transformer protection
The relay provides all the functions for backup protection for
transformer differential protection. The inrush suppression
effectively prevents unwanted trips that can be caused by
inrush currents. The high-impedance restricted ground-fault
protection detects short-circuits and insulation faults on the
transformer.
Programmable logic
Backup protection
3
4
As a backup protection the SIPROTEC 7SJ80 devices are
universally applicable.
Operational measured value
provide improved system management.
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.
5
6
Busbar
Local/remote control
CFC logic
Commands/Feedbacks
52
74TC Trip circuit supervision
86
AND
min/max-memory
Esc
Communication module
RS232/485/FO/
Ethernet
IEC 60870-5-103/4
IEC 61850
PROFIBUS-DP
DNP 3.0
MODBUS RTU
DNP3 TCP
PROFINET
...
Enter
7
8
9
4
1
5
2
6
3
Fn 0
.
7
Synchrocheck
V, f, P
I, V, P, Q,
cos ˳, f
Mean value
Lock out
Operation
25
Limits
P<>, Q<> cos˳ df/dt dV/dt
27R
32
55
81R
59R
1)
Metered energy: as counting pulses
1)
f<, f>
V>
V<
81U/O
59
27
8
Fault Locator
Fault recording
Directional supplement
FL
47
Phase sequence
1)
I>, I>> ITOC
67
9
IN>, IN>>,
IN-TOC
67N
1)
I-TOC
50
51
IN>, IN>>, IN-TOC
IN>>>
50N
51N
I2>
46
!
49
InRush
BLK
79
50N
IN>, IN>>,
IN>>>
AR
BF
REF
51N
87N
IN-TOC
REF
Automatic reclosing
Breaker Failure Protection
High-impedance ground fault differential protection
SVS
Intermitt.
ground fault 50BF
I<
37
51V
Additional Directional ground
fault protection
INs>,
INs>>
67Ns-TOC
AR
67Ns
1)
VN>
59N
1)
Undervoltage
Contr.react.pow.protec.
I2> Unbalanced load protection
! Thermal overload protection
I< Undercurrent monitoring
2_3_Visio-LSA4783b-us.pdf
I>, I>>,
I>>>
1) Not available if function package “Q” (synchrocheck, ANSI 25) is selected.
10
Application sheets
1
2
3
Directional time-overcurrent protection (ANSI 67, 67N)
Overcurrent protection (ANSI 50, 50N, 51, 51N, 51V)
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) are available both for the phase and the
ground elements. The current threshold and the delay time
can be set in a wide range.
Inverse time-overcurrent protection characteristics (IDMTL)
can also be selected and activated. The inverse-time function
provides – as an option – voltage-restraint or voltagecontrolled operating modes
Reset characteristics
4
Time coordination with electromechanical relays are made
easy with the inclusion of the reset characteristics according
to ANSI C37.112 and IEC 60255-3 / BS 142 standards. When
using the reset characteristic (disk emulation), the 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 (disk emulation).
5
6
IEC 60255-3
Inverse

Short inverse
Long inverse
By making use of the voltage memory, the directionality can
be determined reliably even for close-in (local) faults. If the
primary switching device closes onto a fault and the voltage
is too low to determine direction, the direction is determined
using voltage from the memorized voltage. If no voltages are
stored in the memory, tripping will be according to the set
characteristic.
For ground protection, users can choose whether the direction is to be calculated using the zero-sequence or negativesequence system quantities (selectable). If the zero-sequence
voltage tends to be very low due to the zero-sequence impedance it will be better to use the negative-sequence quantities.
ANSI / IEEE



Moderately inverse
7
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 by ± 180
degrees.


Very inverse


Extremely inverse


Table 4/2 Available inverse-time characteristics
Inrush restraint
8
If second harmonic content is detected during the energization of a transformer, the pickup of stages I>,Ip, I>dir
and Ip dir is blocked.
Dynamic settings group switching
9
In addition to the static parameter changeover, the pickup
thresholds and the tripping times for the directional and
non-directional time-overcurrent protection functions can
be changed over dynamically. As changeover criterion, the
circuit-breaker position, the prepared auto-reclosure, or a
binary input can be selected.
Directional comparison protection (cross-coupling)
10
It is used for selective instantaneous tripping of sections
fed from two sources, i.e. without the disadvantage of time
delays of the set characteristic. The directional comparison
protection is suitable if the distances between the protection
zones are not significant and pilot wires are available for
signal transmission. In addition to the directional comparison
protection, the directional coordinated time-overcurrent
protection is used for complete selective backup protection.
Fig. 4/4 Directional characteristics of the directional time-overcurrent
protection
(Sensitive) directional ground-fault detection
(ANSI 59N/64, 67Ns, 67N)
For isolated-neutral and compensated networks, the direction
of power flow in the zero sequence is calculated from the
zero-sequence 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 (see Fig.4/5).
Two modes of ground-fault direction detection can be implemented: tripping or “signalling only mode”.
Application sheets
(ANSI 59N, 67Ns, 67N) (contin.)
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 to forward, reverse or nondirectional
• The function can also be operated in the insensitive mode
as an additional short-circuit protection.
Negative-sequence system overcurrent protection (ANSI 46)
By measuring current on the high side of the transformer,
the two-element phase-balance current/negative-sequence
protection detects high-resistance phase-to-phase faults
and phase-to-ground faults on the low side of a transformer
(e.g. Dy 5). This function provides backup protection for
high-resistance faults through the transformer.
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.
1
2
3
4
5
6
Undervoltage-controlled reactive power protection
Fig. 4/5 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 normal mode as an additional shortcircuit protection for neutral or residual ground protection.
Intermittent (re-igniting) faults are caused by poor cable
insulation or water ingress into cable joints. After some time,
the faults extinguish automatically or they develop into
permanent short circuits. During the intermitting, neutral
point resistances in impedance grounded systems can suffer
thermal overload.
The normal ground fault protection is not capable of reliably
detecting and clearing the sometimes very short current
pulses. The required selectivity for intermittent ground
faults is achieved by summing up the times of the individual
pulses and tripping after a (programmable) summation time
has been reached. The pickup threshold Iie> evaluates RMS
values referred to 1 system period.
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.
trip command can be initiated using the breaker failure protection which trips the circuit-breaker of an upstream feeder.
Breaker failure is detected if, after a trip command is issued
and the current keeps on flowing into the faulted circuit. It is
also possible to make use of the circuit-breaker position contacts for indication as opposed to the current flowing through
the circuit-breaker.
7
8
9
10
Application sheets
1
2
3
4
5
6
The high-impedance measurement principle is a simple
and sensitive method to detect ground faults, especially on
transformers. It can also be used on motors, generators and
reactors when they are operated on a grounded network.
When applying the high-impedance measurement principle,
all current transformers in the protected area are connected
in parallel and operated through one common resistor of
relatively high R. The voltage is measured across this resistor
(see Fig. 4/6).
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 limits the high instantaneous voltage spikes that can
occur at current transformer saturation. At the same time,
this results to smooth the voltage without any noteworthy
reduction of the average value.
If no faults have occurred and in the event of external or
through 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 flowing through the resistor R.
The same type of current transformers must be used and
must at least offer a separate core for the high-impedance
restricted ground-fault protection. They must have the same
transformation ratio and approximately an identical kneepoint voltage. They should also have only minimal measuring
errors.
7
• Initiation of the ARC is dependant on the trip command
selected (e.g. I2>, I>>, Ip, Idir>)
• The ARC function can be blocked by activating a binary input
• The ARC can be initiated from external or by the PLC logic (CFC)
• The directional and non-directional elements can either
be blocked or operated non-delayed depending on the
auto-reclosure cycle
• If the ARC is not ready it is possible to perform a dynamic
setting change of the directional and non-directional
overcurrent elements.
The SIPROTEC 7SJ80 enables the user to easily add up to
20 additional protection functions. Parameter definitions
are used to link standard protection logic with any chosen
three-phase or single-phase. Almost all quantities can be
under and overvoltage). All stages operate with protection
priority.
Current
Voltage
Measured-value
processing
I measured
V measured
3I0, I1, I2
3V0, V1, V2
34
FRV˳
f
df/dt
dV/dt
Parameter
Standard protection logic
(simplified diagram)
Time
t
Pickup
TRIP
command
Threshold
Function 1
Function 2
Function 20
Protection functions/stages available are based on the
available measured analog quantities:
8
LSA4115-de.ai
Function
9
Fig. 4/6 High-impedance restricted ground-fault protection
Automatic reclosing (ANSI 79)
10
Multiple re-close cycles can be set by the user and lockout
will occur if a fault is present after the last re-close cycle.
The following functions are available:
• 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)
ANSI
I>, IE>
50, 50N
V<, V>, VE>
27, 59, 59N
3I0>, I1>, I2>, I2 / I1>, 3V0>, V1> <, V2 > <
50N, 46, 59N, 47
P> <, Q> <
32
cos ϕ
55
f><
81O, 81U
df / dt > <
81R
dV/dt
27R/59R
Table 4/3 Available flexible protection functions
For example, the following can be implemented:
• Reverse power protection (ANSI 32R)
• Rate-of-frequency-change protection (ANSI 81R)
• Rate-of-voltage-change protection (ANSI 27R/59R).
4_7_Visio-flexProFunc-us.pdf
High-impedance restricted ground-fault protection (ANSI 87N)
Application sheets
Synchrocheck, synchronizing function (ANSI 25)
When closing a circuit-breaker, the units can check whether
two separate networks are synchronized. Voltage-, frequency- and phase-angle-differences are checked to determine
whether synchronous conditions exist.
active over a wide frequency range (45 to 55, 55 to 65 Hz).
continues to work, however, with decrease accuracy. The
Lockout (ANSI 86)
To protect cables and transformers, an overload protection
function with an integrated warning/alarm element for
temperature and current can be used. The temperature is
calculated using a thermal homogeneous body model (per
IEC 60255-8), it considers the energy entering the equipment and the energy losses. The calculated temperature is
constantly adjusted according to the calculated losses. The
function considers loading history and fluctuations in load.
Settable dropout delay times
If the relays are used in conjunction with electromechanical
relays, in networks with intermittent faults, the long dropout
times of the electromechanical relay (several hundred milliseconds) can lead to problems in terms of time coordination/
grading. Proper time coordination/grading is only possible if
the dropout or reset time is approximately the same. This is
why the parameter for dropout or reset times can be defined
for certain functions, such as overcurrent protection, ground
short-circuit and phase-balance current protection.
Undercurrent monitoring (ANSI 37)
A sudden drop in current, which can occur due to a reduced
load, is detected with this function. This may be due to shaft
that breaks, no-load operation of pumps or fan failure.
1
2
3
Frequency protection can be used for overfrequency and
underfrequency protection. Electric machines and parts
of the system are protected from unwanted frequency
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 (for 50 Hz), 50 to 70 (for
60 Hz)). There are four elements (individually set as overfrequency, underfrequency or OFF) and each element can
be delayed separately. Blocking of the frequency protection
can be performed by activating a binary input or by using an
undervoltage element.
4
5
6
Fault locator (ANSI 21FL)
The integrated fault locator calculates the fault impedance
and the distance to fault. The results are displayed in Ω,
kilometers (miles) and in percent of the line length.
7
Customized functions (ANSI 51V, 55 etc.)
Additional functions, which are not time critical, can be implemented using the CFC measured values. Typical functions
include reverse power, voltage controlled overcurrent, phase
angle detection, and zero-sequence voltage detection.
8
9
positive phase-sequence or negative phase-sequence voltage. Three-phase and single-phase connections are possible.
10
Application sheets
Further functions
1
Measured values
and voltage along with the power factor, frequency, active
and reactive power. The following functions are available for
measured value processing:
2
• Symmetrical components I1, I2, 3I0; V1, V2, 3V0
selective)
3
• Frequency
• Mean as well as minimum and maximum current and
voltage values
4
• Limit value monitoring
indication.
5
• Zero suppression
In a certain range of very low measured values, the value
is set to zero to suppress interference.
6
Metered values
the SIPROTEC 7SJ80 can obtain and process metering pulses
through an indication input. The metered values can be displayed and passed on to a control center as an accumulated
value with reset. A distinction is made between forward,
reverse, active and reactive energy.
7
8
Circuit-breaker wear monitoring/
circuit-breaker remaining service life
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 exact mathematical method to calculate the wear
or the remaining service life of a circuit-breaker that takes
arc-chamber’s physical conditions into account 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 relay offers several methods:
• ΣI
• ΣIx, with x = 1..3
• Σi2t.
The devices also offer a new method for determining the
remaining service life:
• Two-point method
The CB manufacturers double-logarithmic switching cycle
diagram (see Fig. 4/8) 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 remaining
number of possible switching cycles. 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.
Binary I/O extension with SICAM I/O-Unit 7XV5673
To extend binary inputs and binary outputs for SIPROTEC
7SJ80 up to two SICAM I/O-Units 7XV5673 can be added.
Each SICAM I/O-Unit 7XV7653 is equipped with 6 binary
inputs and 6 binary outputs and an Ethernet switch for
cascading. The connection to the protection device can be
either through the DIGSI Ethernet service interface Port A or
through IEC 61850 GOOSE on Port B (System interface with
EN100 module).
9
10
P1: Permissible number
of operating cycles
at rated normal
current
of operating cycles
at rated shortcircuit current
Fig. 4/8 Permissible number of operating cycles as a function of
breaking current
Application sheets
Commissioning
Commissioning could not be easier and is 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 relay. The analog measured values are
represented as wide-ranging operational measured values.
To prevent transmission of information to the control center
during maintenance, the communications can be disabled
to prevent unnecessary data from being transmitted. During
commissioning, all indications with test tag for test purposes
can be connected to a control and protection system.
1
2
3
Test operation
During commissioning, all indications with test tag can be
passed to a control system for test purposes.
4
5
6
7
8
9
10
Radial systems
General hints:
The relay at the far end (D) from the
infeed has the shortest tripping time.
Relays further upstream have to be
time-graded against downstream
relays in steps of about 0.3 s.
1
2
Infeed
1) Auto-reclosure
(ANSI 79) only with
overhead lines
2) Unbalanced load
protection (ANSI 46)
as backup protection
against asymmetrical
faults
A
52
Busbar
Further power supply B
52
I>t
IN>t
I2>t
AR
51
51N
46
79
2)
3
1)
Busbar
*
C
52
4
I>t
IN>t
I2>t
51
51N
46
Load
Busbar
*
6
Load
D
52
I>t
IN>t
I2>t
51
51N
46
Load
Fig. 4/9 Protection concept with time-overcurrent protection
7
Earth-fault detection in isolated or
compensated systems
8
In isolated or compensated systems,
an occurred earth fault can be easily
found by means of sensitive directional earth-fault detection.
1) The sensitive current
measurement of the
earth current should
be made by a zerosequence current
transformer
Infeed
Busbar
9
7XR96
1)
60/1
10
Load
I>>
I>t
50
51
IN>t dir.
67Ns
4_10_LSA4840a-en.pdf
52
Fig. 4/10 Protection concept for directional earth-fault detection
4_9_LSA4839-en.pdf
5
Ring-main cable
For lines with infeed from two sources, no selectivity can be achieved
with a simple definite-time overcurrent protection. Therefore, the
directional definite-time overcurrent
protection must be used. A nondirectional definite-time overcurrent
protection is enough only in the
corresponding busbar feeders. The
grading is done from the other end
respectively.
Advantage:
100% protection of the
line via instantaneous
tripping, and easy
setting.
Infeed
1
Infeed
52
52
52
I>t
IN>t
ȣ>t
I2>t
51
51N
49
46
2
Direct.Compar.Pickup
Overhead line
or cable 1
Overhead line
or cable 2
I>t
IN>t dir.
I>t
IN>t
67
67N
51
51N
Protection as in
the case of line
or cable 1
3
52
52
52
52
Disadvantage: Tripping times increase
towards the infeed.
4
52
67
67N
51
51N
I>t
IN>t dir.
I>t
IN>t
Overhead line
or cable 3
Overhead line
or cable 4
I>t
IN>t dir.
I>t
IN>t
67
67N
51
51N
52
5
Protection as in
the case of line
or cable 3
6
52
52
52
52
I>t
IN>t
ȣ>t
I2>t
51
51N
49
46
Load
Load
With the directional comparison
protection, 100% of the line can be
protected via instantaneous tripping
in case of infeed from two sources
(ring-main cable).
7
Fig. 4/11 Protection concept of ring power systems
8
9
10
Busbar protection by overcurrent
relays with reverse interlocking
1
Infeed
Applicable to distribution busbars
without substantial (< 0.25 x IN)
backfeed from the outgoing feeders.
Reverse interlocking
I>>t0
2
50/50N
52
51/51N
t0 = 50 ms
Busbar
52
52
I>>
I>t
I>>
I>t
I>>
I>t
50/50N
51/51N
50/50N
51/51N
50/50N
51/51N
4
Fig. 4/12 Busbar protection via overcurrent relays with reverse interlocking
5
Line feeder with load shedding
6
7
8
Busbar
52
V<
f<
27
81U
I>, I>>,
I>>>
IN>>
I>, Ip
IN>,
INTOC
50
50N
51
51N
>
I2>
Final trip
79M
49
46
86
Fig. 4/13 Line feeder with load shedding
9
10
4_13_LSA2216b-en.pdf
In unstable power systems (e.g. solitary systems, emergency power supply in hospitals), it may be necessary
to isolate selected consumers from
the power system in order to protect
the overall system. The overcurrenttime 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.
52
3
Automatic reclosing
Reverse power protection with parallel
infeeds
If a busbar is supplied by two parallel
infeeds and there is a fault in one of the
infeeds, the affected busbar shall be
selectively shut down, so that supply to
the busbar is still possible through the
remaining infeed. To do this, directional
devices are required, which detect a
short circuit from the busbar towards the
infeed. In this context, the directional
time-overcurrent protection is normally
adjusted over the load current. Lowcurrent faults cannot be shut down by this
protection. The reverse power protection
can be adjusted far below rated power,
and is thus also able to detect reverse
power in case of low-current faults far
below the load current. The reverse power
protection is implemented through the
“flexible protection functions”.
Stage can
be blocked
52
1
Stage get slower executes the
than the fuse or
reclosing for
lower protection the hole feeder
devices graduated
2
ON
52
TRIP
I>, I>>, I>>>
I>t, I>>t, Ip
50
51
IN>t, IN>>t,
INTOC
IN>>
50N
AR
51N
79
4_14_LSA2219d-en.pdf
52
3
Fuse opens by
unsuccessful reclosing
52
4
I>t, Ip
Circuit-breaker opens
by unsuccessful reclosing
67
5
Fig. 4/14 Auto-reclosure
Infeed
A
Infeed
B
6
52
52
7
67
67N
32R
67
67N
32R
52
52
52
Feeder
Feeder
The Automatic reclosing function (AR)
has starting and blocking options. In the
opposite example, the application of the
blocking of the high-current stages is
represented according to the reclosing
cycles. The overcurrent protection is
graded (stages I, Ip) according to the
grading plan. If an Automatic reclosing
function is installed in the incoming supply
of a feeder, first of all the complete feeder
is tripped instantaneously in case of fault.
Arc faults will be extinguished independently of the fault location. Other protection relays or fuses do not trip (fuse saving
scheme). After successful Automatic
reclosing, all consumers are supplied with
energy again. If there is a permanent fault,
further reclosing cycles will be performed.
Depending on the setting of the AR, the
instantaneous tripping stage in the infeed
is blocked in the first, second or third cycle,
i.e., now the grading is effective according
to the grading plan. Depending on the
fault location, overcurrent relays with
faster grading, fuses, or the relay in the
infeed will trip. Only the part of the feeder
with the permanent fault will be shut
down definitively.
8
9
Fig. 4/15 Reverse power protection with parallel infeeds
10
Synchrocheck
2
3
Busbar
V2
52
Closing Signal
1
Transformer
Local/remote
control
VT1
1)
2
25
SYN
2)
81
G
Infeed
1)
2)
4
4_16_LSA4114-us.pdf
Where two system sections are interconnected, the synchrocheck determines whether the connection is permissible without danger to the stability
of the power system. In the example,
load is supplied from a generator
to a busbar through a transformer.
The vector group of the transformer
can be considered by means of a
programmable angle adjustment, so
that no external adjustment elements
are necessary. Synchrocheck can be
used for auto-reclosure, as well as for
control functions (local or remote).
1
AR
Synchrocheck
Automatic reclosing
Fig. 4/16 Measurement of busbar and feeder voltage for synchronization
Protection of a transformer
5
The high-current stage enables a current grading, the overcurrent stages
work as backup protection to subordinate protection devices, and the overload function protects the transformer
from thermal overload. Low-current,
single-phase faults on the lowvoltage side, which are reproduced
in the opposite system on the highvoltage side, can be detected with
the unbalanced load protection. The
available inrush blocking prevents
pickup caused by the inrush currents
of the transformer.
6
7
8
Busbar
High-voltage
59-1 PU ,t
59
52
TRIP
I>, I>>
I>t, I>>t, Ip
>t
I2>t, I2>>t
50
51
49
46
IN>, IN>>
IN>t, IN>>t,
INTOC
50N
51N
Inrush blocking
52
87
e.g.
7UT61
52
*
9
IN>, IN>>
IN>t, IN>>t, INTOC
50N
51N
52
Busbar
Medium-voltage
52
52
52
TRIP
I2>>t, I2>t I>, I>> I>t, I>>t, Ip
46
50
typical Feeder
10
Unbalanced fault
Fig. 4/17 Typical protection concept for a transformer
51
4_17_LSA2203b-us.pdf
52
Undervoltage-controlled reactive
power protection (QV Protection)
This ensures that generating units disconnect from the power system which
additionally burden the power system
during a short circuit or prevent that
the power system is restored when
connecting after a short circuit. The
monitoring of the voltage support
also fulfills this function.
Using the criteria mentioned above
the QV protection disconnects the generating unit from the power system
after a programmable time.
The QV protection furthermore allows
releasing the re-connection after the
fault has been located and cleared
in the power system and the system
voltage and frequency are stable
again.
1
Power transformer
Busbar
Further
feeders
2
Circuit breaker at the power-system connection point
*
52
Tripping
I>, I>>
I-TOC
50
51
IN>, IN>> IN-TOC
50N
51N
V>, V>>
V<
f>, f>
Q>/ V<
59
27
81
1)
1)
Undervoltage
controlled reactive
power protection
3
Medium-voltage busbar
4
Generator step-up transformers
Bus coupler circuit-breaker
52
G
3~
Fig. 4/18
52
G
3~
52
G
3~
Decoupling protection
with V>>, V<, V<<, f>, f< functionen
Generators
4_18_Visio-QU-Schutz-en.pdf
When connecting generating units
to the medium-voltage power
system of the operator, a protective
disconnection device is required
which takes into account frequency
and voltage and also evaluates the
reactive power direction. When the
generating unit draws reactive power
from the operator's power system,
Undervoltage-controlled reactive
power protection (Q> & V<) links
the reactive power with all three
phase-to-phase voltages falling below
a limiting value using a logical AND
operation.
5
6
Application directional intermittent ground fault protection
7
8
9
10
Product description
1
Order No.
Short code
12345 6 7
Overcurrent Protection 7SJ80 V4.7
7SJ80
8 9 10 11 12 13 14 15 16 17 18 19
-
-
+
Measuring inputs, binary inputs and outputs
2
Housing 1/6 19"; 4 x I, 3 BI, 5 BO (2 Changeover/Form C), 1 life contact
1
2
Housing 1/6 19"; 4 x I, 3 x V, 3 BI, 5 BO (2 Changeover/Form C), 1 life contact
3
4
7
8
see
next
page
Measuring inputs, default settings
3
Iph = 1A / 5A, Ie =1A / 5A
1
Iph = 1A / 5A, Iee (sensitive) = 0,001 to 1,6A / 0,005 to 8A
2
Auxiliary voltage
4
DC 24 V / 48 V
1
DC 60 V / 110 V / 125 V / 220 V / 250 V, AC 115 V, AC 230 V
5
Construction
Surface-mounting case, screw-type terminal
Flush-mounting case, screw-type terminal
5
B
E
Region specific default and language settings
6
7
Region DE, IEC, language German (language changeable), standard front
A
Region World, IEC/ANSI, language Englisch (language changeable), standard front
B
Region US, ANSI, language US-English (language changeable), US front
C
Region FR, IEC/ANSI, language French (language changeable), standard front
D
Region World, IEC/ANSI, language Spanish (language changeable), standard front
E
Region World, IEC/ANSI, language Italian (language changeable), standard front
F
Region RUS, IEC/ANSI, language Russian (language changeable), standard front
G
Region CHN, IEC/ANSI, language Chinese (language not changeable), Chinese front
K
Port B (at bottom of device, rear)
No port
IEC60870-5-103 or DIGSI4/Modem, electrical RS232
IEC60870-5-103 or DIGSI4/Modem, electrical RS485
IEC60870-5-103 or DIGSI4/Modem, optical 820nm, ST connector
PROFIBUS DP Slave, electrical RS485
PROFIBUS DP Slave, optical, double ring, ST connector
MODBUS, optical 820nm, ST connector
DNP 3.0, optical 820nm, ST connector
IEC 61850, 100Mbit Ethernet, electrical, double, RJ45 connector
IEC 61850, 100Mbit Ethernet, optical, double, LC connector
DNP3 TCP + IEC 61850, 100Mbit Ethernet, electrical, double, RJ45 connector
DNP3 TCP + IEC 61850, 100Mbit Ethernet, optical, double, LC connector
PROFINET + IEC 61850, 100Mbit Ethernet, electrical, double, RJ45 connector
PROFINET + IEC 61850, 100Mbit Ethernet, optical, double, LC connector
8
9
IEC 60870-5-104 + IEC 61850, 100Mbit Ethernet, electrical,double, RJ45 connector
IEC 60870-5-104 + IEC 61850, 100Mbit Ethernet, optical, double, LC connector
10
0
1
2
3
9
9
9
L 0 A
L 0 B
L 0 D
L 0 E
9
9
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
9
9
9
9
9
9
9
9
9
L 4 R
9
L 4 S
Port A (at bottom of device, in front)
No port
0
With Ethernet interface (DIGSI, I/O-Unit connection, not IEC61850), RJ45 connector
6
Measuring/Fault Recording
With fault recording
1
With fault recording, average values, min/max values
3
ANSI No.
Product description
Order No.
Bestell-Nr.
Short code
12345 6 7
7SJ80
8 9 10 11 12 13 14 15 16 17 18 19
-
Basic version
50/51
50N/51N
50N(s)/51N(s)1)
87N2)
49
74TC
50BF
46
37
86
27R/32/55/59R/81R
F A
27R/32/55/59R/81R
3
F B
27R/32/55/59R/81R
4
4)
Directional time-overcurrent protection, ground, IE>, IE>>, IE>>>, IEp
Directional sensitive ground fault protection, IEE>, IEE>>, IEEp
Displacement voltage
Under/Overvoltage
Under/Overfrequency, f<, f>
Phase rotation
Flexible protection functions (current and voltage parameters)): Protective function for voltage,
power, power factor, rate-of-frequency change, rate-of-voltage change
5
F C
6
4)
Directional time-overcurrent protection, phase, I>, I>>, I>>>, Ip
Directional time-overcurrent protection, ground, IE>, IE>>, IE>>>, IEp
Sensitive ground-fault protection, IEE>, IEE>>, IEEp
Under/Overvoltage
Phase rotation
7
Basic functionality + Directional phase & ground overcurrent, directional sensitive ground
F F
fault, voltage and frequency protection + Undervoltage controlled reactive power protection
+ Directional intermittent ground fault protection
51V
67
67N
67Ns1)
67Ns2)
64/59N
27/59
81U/O
27Q
47
3)
2
Basic functionality + Directional phase & ground overcurrent,
directional sensitive ground fault, voltage and frequency protection
51V
67
67N
67Ns1)
64/59N
27/59
81U/O
47
1
+
Time-overcurrent protection, phase I>, I>>, I>>>, Ip
Time overcurrent protection, ground IE>, IE>>, IE>>>, IEp
Sensitive ground fault protection IEE>, IEE>>, IEEp
High impedance REF
Overload protection
Negative-sequence system overcurrent protection
Lockout
Parameter changeover
Control of circuit breaker
Flexible protection functions (current parameters)
Inrush restraint
Basic functionality + Directional sensitive ground fault, voltage and frequency protection
51V
67N
67Ns1)
64/59N
27/59
81U/O
47
-
Directional overcurrent protection, phase, I>, I>>, I>>>, Ip
Directional overcurrent protection, ground, IE>, IE>>, IE>>>, IEp
Directional sensitive ground fault protection, IEE>, IEE>>, IEEp
Under/Overvoltage
Undervoltage controlled reactive power protection, Q>/V<
Phase rotation
8
4)
9
see
next
page
10
1) Depending on the ground current input the function will be either sensitive (IEE) or non-sensitive (IE)
2) Function only available with sensitive ground current input (Position 7=2)
3) Only if position 6 = 1, 2 or 7
You will find a detailed overview of the technical data (extract of the manual) under: http://www.siemens.com/siprotec
ANSI No.
Product description
Order No.
Bestell-Nr.
Short code
12345 6 7
1
7SJ80
8 9 10 11 12 13 14 15 16 17 18 19
-
Basic functionality + Directional phase overcurrent, voltage and frequency protection +
synchrocheck
2
51V
67
27/59
81U/O
47
25
27R/59R/81R
3
-
+
F Q
5)
Directional time-overcurrent protection, phase, I>, I>>, I>>>, Ip
Under/Overvoltage (phase-to-phase)
Under/Overfrequency, f< ,f>
Phase rotation
Synchrocheck
rate-of-frequency change, rate-of-voltage change
Automatic Reclosing (AR), Fault Locator (FL)
4
Without
0
79
With automatic reclosure function
1
21FL
With FL (only with position 6 = 3, 4 or 8)
2
79/FL
With automatic reclosure function and FL (only with position 6 = 3, 4 or 8)
3
5
6
7
8
9
10
5) Only with position 6 = 3 or 4 and position 16 = 0 or 1
Connection diagrams
1
IA
F1
F2
F3
F4
F5
F6
F7
F8
I B, IN2
BO1
C11
C9
C10
BO2
C14
C13
C12
2
BO3
E1
E2
E3
E4
E5
E6
3
IC
I N, INS
BO4
BO5
C3
C4
C5
C6
C7
C8
4
BI1
BI2
Life Contact
E10
E8
E7
=
(~)
Power Supply
=
+
-
C1
C2
6
Port B
Port A
Ethernet interface
4_19_LSA4784us.pdf
USB-DIGSI-Interface
5
B
A
7
250 V
BI3
8
Fig. 4/19 Multifunction protection SIPROTEC 7SJ801
9
10
Connection diagrams
1
IA
F1
F2
F3
F4
F5
F6
F7
F8
C11
C9
C10
BO2
C14
C13
C12
BO3
E1
E2
E3
E4
E5
E6
D9
D10
D11
D12
D13
D14
IC
I N, INS
BO4
3
BO5
BO6
4
5
6
BO7
C3
C4
C5
C6
C7
C8
BI1
D1
D2
D3
D4
D5
D6
D7
D8
BI4
BO8
BI2
BI3
E10
E8
E7
Life Contact
=
BI5
(~)
Power Supply
=
BI7
7
C1
C2
Port B
4_20_LSA4785us.pdf
USB-DIGSI-Interface
9
-
BI6
Port A
Ethernet interface
8
+
10
B
A
250 V
2
I B, IN2
BO1
Connection diagrams
1
IA
F1
F2
F3
F4
F5
F6
F7
F8
I B, IN2
BO1
C1 1
C9
C10
BO2
C1 4
C13
C12
2
BO3
E1
E2
E3
E4
E5
E6
3
IC
I N, INS
BO4
E9 Q2
E11
E12
E13
E14
VA, VAB, Vph-n
VB, VBC
BO5
VC, VN, Vsyn, VX
C3
C4
C5
C6
C7
C8
4
BI1
BI2
BI3
=
+
-
C1
C2
6
Port B
Port A
Ethernet interface
USB-DIGSI-Interface
B
A
7
250 V
=
(~)
Power Supply
4_21_LSA4786us.pdf
5
E10
E8
E7
Life Contact
8
9
10
Connection diagrams
1
IA
F1
F2
F3
F4
F5
F6
F7
F8
4
5
6
BO2
C1 4
C13
C12
BO3
E1
E2
E3
E4
E5
E6
D9
D10
D11
D12
D13
D14
IC
I N, INS
BO4
E9 Q2
E11
E12
E13
E14
3
C1 1
C9
C10
VA, VAB, Vph-n
VB, VBC
BO5
VC, VN, Vsyn, VX
BO6
BO7
C3
C4
C5
C6
C7
C8
BI1
D1
D2
D3
D4
D5
D6
D7
D8
BI4
BO8
BI2
BI3
E10
E8
E7
Life Contact
=
BI5
(~)
Power Supply
=
BI7
7
C1
C2
Port B
4_22_LSA4787us.pdf
USB-DIGSI-Interface
9
-
BI6
Port A
Ethernet interface
8
+
10
B
A
250 V
2
I B, IN2
BO1
Connection diagrams
1
IA
I B, IN2
BO1
C1 1
C9
C10
BO2
C1 4
C13
C12
2
BO3
E1
E2
E3
E4
E5
E6
3
IC
I N, INS
BO4
4_23_Visio-kl-uebers-7sx807-us.pdf
BO5
C3
C4
C5
C6
C7
C8
BI1
D1
D2
D3
D4
D5
D6
D7
D8
D9
D10
D11
D12
D13
D14
BI4
4
BI2
BI3
=
BI5
5
E10
E8
E7
Life Contact
(~)
Power Supply
=
+
-
C1
C2
6
BI6
BI7
Port B
BI8
BI9
Port A
Ethernet interface
BI10
BI11
USB-DIGSI-Interface
B
A
7
250 V
F1
F2
F3
F4
F5
F6
F7
F8
8
9
10
Connection diagrams
1
2
E9 Q2
E11
E12
E13
E14
3
4
5
6
4_24_Visio-kl-uebers-7sx808-us.pdf
7
8
IA
I B, IN2
BO1
C1 1
C9
C10
BO2
C1 4
C13
C12
BO3
E1
E2
E3
E4
E5
E6
IC
I N, INS
BO4
VA, VAB, Vph-n
VB, VBC
BO5
VC, VN, Vsyn, VX
C3
C4
C5
C6
C7
C8
BI1
D1
D2
D3
D4
D5
D6
D7
D8
D9
D10
D11
D12
D13
D14
BI4
BI2
BI3
E10
E8
E7
Life Contact
=
BI5
(~)
Power Supply
=
-
C1
C2
BI6
BI7
Port B
BI8
BI9
Port A
Ethernet interface
BI10
BI11
USB-DIGSI-Interface
9
+
10
B
A
250 V
F1
F2
F3
F4
F5
F6
F7
F8
Connection examples
Connection of current
and voltage transformers
Standard connection
52
52
52
P2
S2
P1
S1
A
B
F1
IA
F2
F3
IB
F4
F5
IC
F6
IN
F7
2
4_25_LSA4789-en.pdf
For grounded networks, the ground
current is obtained from the phase
currents by the residual current
circuit.
1
A
B
C
F8
SIPROTEC
C
3
Fig. 4/25 Residual current circuit without directional element
4
A
B
C
A
B
b
5
a
VA-N
52
52
52
VB-N
E12
E13
VC-N
E14
IA
F1
l
K
k
A
B
F6
IN
F7
C
F4
IC
F5
L
F2
IB
F3
F8
6
4_26_LSA4791-en.pdf
E9
E11
7
SIPROTEC
8
Fig. 4/26 Residual current circuit with directional element
52
52
F1
F3
F5
L
l
K
k
A
B
C
L
l
K
k
9
52
F8
IA
IB
IC
INs
SIPROTEC
F2
F4
F6
F7
For power systems with small earth
currents, e.g. isolated or compensated systems, the earth current is
measured by a zero-sequence current
transformer.
A
B
C
10
Fig. 4/27 Sensitive ground current detection without directional element
Connection examples
Connection for compensated
networks
2
3
A
B
C
A
B
da
dn
a
b
52
52
52
E9
VA-B
E11
VC-B
E12
E13
VN
E14
F1
F3
F5
4
L
l
K
k
A
5
B
C
L
l
K
k
F8
IA
LSA4792a-en.pdf
1
The figure shows the connection of
two phase-to-ground voltages and
the VE voltage of the broken 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.
F2
IB
F4
IC
F6
INs
F7
SIPROTEC
Fig. 4/28 Sensitive directional ground-fault detection with directional
element for phases
6
Sensitive directional ground-fault
detection.
A
B
C
A
7
B
da
52
52
52
E13
8
F1
F3
F5
9
L
l
K
k
A
B
C
L
l
K
k
F8
VN
IA
IB
IC
INs
SIPROTEC
Fig. 4/29 Sensitive directional ground-fault detection
10
E14
F2
F4
F6
F7
dn
Connection examples
Connection for the synchrocheck
function
52
52
52
A
B
1
a
b
E9
A
a
B
A
b
a
B
b
E11
F1
F3
l
K
k
A
B
C
2
E12
E14
E13
L
VA-B
VC-B
VSyn
IA
IB
3
F2
F4
F5
IC
F8
F7
IN
F8
4_30_LSA4858-en.pdf
If no directional earth-fault protection
is used, connection can be done with
just two phase current transformers.
For the directional phase short-circuit
protection, the phase-to-phase
voltages acquired with two primary
transformers are sufficient.
A
B
C
4
SIPROTEC
Fig. 4/30 Measuring of the busbar voltage and the outgoing feeder
voltage for synchronization
5
6
7
8
9
10
Connection types
Overview of connection types
1
2
3
4
Type of network
Function
Current connection
Voltage connection
(Low-resistance) grounded
networks
Time-overcurrent protection
phase/ground non-directional
Residual circuit, with 3 phasecurrent transformers required,
phase-balance neutral current
transformers possible
–
networks
Sensitive ground-fault protection
Phase-balance neutral current
transformers required
–
Isolated or compensated
networks
Overcurrent protection phases
non-directional
Residual circuit, with 3 or 2 phasecurrent transformers possible
–
networks
Directional time-overcurrent
protection, phase
Residual circuit, with 3 phasecurrent transformers possible
Phase-to-ground connection or
phase-to-phase connection
networks
Directional time- overcurrent
protection, phase
networks
protection, ground-faults
Phase-to-ground connection
required
Isolated networks
Residual circuit, if ground current
> 0.05 IN on secondary side,
otherwise phase-balance neutral
current transformers required
3 times phase-to-ground
connection or phase-to-ground
connection with broken delta
winding
Compensated networks
cos ϕ measurement
winding
5
Table 4/4 Overview of connection types
6
7
8
9
10
SIPROTEC Compact
Overcurrent Protection 7SJ81
for Low-Power CT and VT Applications
Page
1
2
3
Description
5/3
Function overview
5/4
Applications
5/5
Application sheets
5/6
5/12
5/14
Connection diagrams
5/16
Connection examples
5/20
4
5
6
7
8
9
10
for Low-Power CT and VT Applications – Description
Description
The SIPROTEC 7SJ81 provides 4 low-power current transformer inputs and optionally 3 low-power voltage transformer
inputs. With the same low-power current transformer (LPCT)
a wide range of primary rated line currents can be covered.
Objects with rated currents in the range of 40 A to 5000 A
can be protected when using low-power current transformers. The following low-power current transformer ratios are
suitable for the following primary current operating ranges:
1
2
LSP3.01-0024.eps
• 100 A/225 mV for a primary operating current range
of 40 A … 600 A
• 50 A/22.5 mV for a primary operating current range
of 200 A … 3000 A
• 400 A/225 mV for a primary operating current range
of 200 A … 2500 A
• 100 A/22.5mV for a primary operating current range
of 400A … 5000 A
4
The SIPROTEC 7SJ81 is a multi-functional motor protection
relay. It is designed for protection of asynchronous motors
of all sizes. The relays have all the required functions to be
applied as a backup relay to a transformer differential relay.
The relay provides numerous functions to respond flexibly to
the system requirements and to deploy the invested capital
economically. Examples for this are: exchangeable interfaces,
flexible protection functions and the integrated automation
level (CFC). Freely assignable LEDs and a six-line display
ensure a unique and clear display of the process states.
In combination with up to 9 function keys, the operating
personnel can react quickly and safely in any situation. This
guarantees a high operational reliability.
3
5
Bild 5/1 SIPROTEC 7SJ81 front view
6
Highlights
7
• Inputs for Low power CTs and VTs according IEC 61869-6
(formerly IEC 60044-7 and IEC 60044-8)
• Removable terminal blocks
LSP3.01-0025.eps
• 6-line display
• USB front port
8
9
Ethernet rings
Bild 5/2 SIPROTEC 7SJ81 rear view
IEC 61850 GOOSE
Ethernet with SNTP.
10
for Low-Power CT and VT Applications – Function overview
1
2
3
IEC
ANSI No.
Instantaneous and definite time-overcurrent protection (phase/neutral)
I>, I>>, I>>>, IE>, IE>>, IE>>>; Ip, IEp
50, 50N; 51, 51N
Directional time-overcurrent protection
Idir>, I>>, Ip dir
67
Directional time-overcurrent protection for ground-faults
IE dir>, IE dir>>, IEp dir
67N
Directional/non-directional sensitive ground-fault detection
IEE>, IEE>>, IEEp
67Ns , 50Ns
V E, V 0>
59N
AKU
74TC
I<
37
Inrush restraint
ϑ>
49
V<, V>
27/59
f<, f>
81O/U
Phase-balance current protection (negative-sequence protection)
I 2>
46
Unbalance-voltage protection and/or phase-sequence monitoring
V2>, phase sequence
47
Breaker failure protection
4
5
50BF
Automatic reclosing
79
Fault locator
FL
Lockout
86
Forward-power, reverse-power protection
P<>, Q<>
32
Power factor
cos ϕ
55
df / dt
81R
6
7
• Operational measured values I, V, f
– IEC 60870-5-103
– PROFIBUS-DP
– DNP 3.0
– MODBUS RTU
• Ethernet interface for DIGSI 4
• Energy metering values Wp, Wg
• Control through keyboard, binary inputs, DIGSI 4 or
SCADA system
8
9
Hardware
• Trip-circuit supervision (74TC)
• 4 current inputs
• Fuse failure monitor
• 0/3 voltage inputs
• 3/7 binary inputs (thresholds configurable using software)
• 5/8 binary outputs (2 changeover/Form C contacts)
• 1 life contact
• Pluggable voltage terminals.
10
for Low-Power CT and VT Applications– Applications
Operational indications
The SIPROTEC 7SJ81 unit is a numerical protection with low
power CT and VT inputs. The device performs control and
monitoring functions and therefore provides the user with a
cost-effective platform for power system management, that
ensures reliable supply of electrical power to the customers.
The ergonomic design makes control easy from the relay
front panel. A large, easy-to-read display was a key design
factor.
Event logs, trip logs, fault records and statistics documents
are stored in the relay to provide the user or operator with all
the key data required to operate modern substations.
1
Line protection
The SIPROTEC 7SJ81 units can be used for line protection
of high and medium-voltage networks with grounded,
point.
Control
control or automation system (e.g. SICAM).
2
Programmable logic
The relay provides all the functions for backup protection for
transformer differential protection. The inrush suppression
effectively prevents unwanted trips that can be caused by
inrush currents.
3
Backup protection
4
SIPROTEC 7SJ81 can be used as a backup protection for a
wide range of applications.
Extensive measured values (e.g. I, V), metered values (e.g.
Wp,Wq) and limit values (e.g. for voltage, frequency) provide
improved system management.
of medium-voltage applications. In general, no separate
measuring instruments (e.g., for current, voltage, frequency, …) or additional control components are necessary in the
cubicles.
5
6
Busbar
CFC logic
86
AND
Esc
min/max-memory
RS232/485/FO/
Ethernet
IEC 60870-5-103
IEC 61850
PROFIBUS-DP
DNP 3.0
MODBUS RTU
Enter
7
8
9
4
1
5
2
6
3
Fn 0
.
I, V, P, Q,
cos ˳, f
Mean value
Lock out
Operation
V, f, P
Limits
P<>, Q<>
cos˳
df/dt
32
55
81R
f<, f>
V>
V<
81U/O
59
27
Fault Locator
Fault recording
FL
47
Phase sequence
monitoring
I>, I>> ITOC
67
I>, I>>,
I>>>
50
I-TOC
51
IN>, IN>>,
IN>>> IN-TOC
50N
51N
I2>
46
>
49
InRush
BLK
79
50N
BF
I<
50BF
37
INs>,
INs>>
67Ns-TOC
AR
67Ns
9
IN>, IN>>,
IN-TOC
67N
fault protection
51N
IN>, IN>>, IN-TOC
IN>>>
AR Automatic reclosing
BF Breaker Failure Protection
8
VN>
59N
52
7
Commands/Feedbacks
10
for Low-Power CT and VT Applications – Application sheets
1
2
Overcurrent protection (ANSI 50, 50N, 51, 51N)
can also be selected and activated.
3
4
Time coordination with electromechanical relays is made
to ANSI C37.112 and IEC 60255-3/BS 142 standards. When
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 by ± 180
degrees.
By making use of the voltage memory, the directionality can
be determined reliably even for close-in (local) faults. If the
primary switching device closes onto a fault and the voltage
is too low to determine direction, the direction is determined
using voltage from the memorized voltage. If no voltages are
stored in the memory, tripping will be according to the set
characteristic.
For ground protection, users can choose whether the direction is to be calculated using the zero-sequence or negativesequence system quantities (selectable). If the zero-sequence
voltage tends to be very low due to the zero-sequence impedance it will be better to use the negative-sequence quantities.
5
IEC 60255-3
Inverse

Short inverse
Long inverse
6
ANSI / IEEE



Moderately inverse


Very inverse


Extremely inverse


7
8
9
Inrush restraint
If second harmonic content is detected during the energization of a transformer, the pickup of stages I >, Ip, I >dir
10
protection is suitable if the distances between the protection
zones are not significant and pilot wires are available for
signal transmission. In addition to the directional comparison
protection, the directional coordinated time-overcurrent
protection is used for complete selective backup protection.
Fig. 5/4 Directional characteristics of the directional
time-overcurrent protection
(ANSI 59N/64, 67Ns, 67N)
For isolated-neutral and compensated networks, the direction of power flow in the zero sequence is calculated from
the zero-sequence 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 low-resistance grounded networks with ohmicinductive current, the tripping characteristics can be rotated
approximately ± 45 degrees (see Fig.5/5).
Two modes of ground-fault direction detection can be
implemented: tripping or “signalling only mode”.
one user-defined characteristic.
• Each element can be set to forward, reverse or
non-directional.
circuit. It is also possible to make use of the circuit-breaker
position contacts (52a or 52b) for indication as opposed to
the current flowing through the circuit-breaker.
1
Automatic reclosing (ANSI 79)
2
• 3-pole ARC for all types of faults
• Multiple ARC, one rapid auto-reclosure (RAR) and up to
nine delayed auto-reclosures (DAR)
3
selected (e.g. I2>, I>>, Ip, Idir >)
• The ARC function can be blocked by activating a binary
input
• The ARC can be initiated from external or by the PLC logic
(CFC)
• The directional and non-directional elements can either
be blocked or operated non-delayed depending on the
auto-reclosure cycle
(ANSI 50Ns, 51Ns / 50N, 51N)
transformer is connected to a split-core low-power current
The SIPROTEC 7SJ81 enables the user to easily add up to
20 additional protection functions. Parameter definitions
under and overvoltage). All stages operate with protection
priority.
4
5
6
7
8
Current
Voltage
Measured-value
processing
I measured
V measured
3I0, I1, I2
3V0, U1, U2
34
FRV˳
f
df/dt
Parameter
Time
t
Threshold
Function 1
Function 2
Function 20
Pickup
TRIP
command
5_6_Visio-flexProFunc-us.pdf
protection detects high-resistance phase-to-phase faults
and phase-to-ground faults on the low side of a transformer
(e.g. Dy 5). This function provides backup protection for
high-resistance faults through the transformer.
9
If a faulted portion of the electrical circuit is not disconnected when a trip command is issued to a circuit-breaker,
another trip command can be initiated using the breaker failure protection which trips the circuit-breaker of an upstream
feeder. Breaker failure is detected if, after a trip command
is issued and the current keeps on flowing into the faulted
Fig. 5/6 Flexible protection function
10
1
2
3
Function
ANSI
I>, IE>
50, 50N
V<, V>, VE>
27, 59, 59N
3I0>, I1>, I2>, I2 / I1>, 3V0>, V1> <, V2 > <
50N, 46, 59N, 47
P> <, Q> <
32
cos ϕ
55
f><
81O, 81U
df / dt > <
81R
5
Lockout (ANSI 86)
9
8
4
7
• Rate-of-frequency-change protection (ANSI 81R).
6
circuit-breaker trip coil including its incoming cables. An
alarm signal is generated whenever the circuit is interrupted.
times of the electromechanical relay (several hundred milliseconds) can lead to problems in terms of time coordination/grading. Proper time coordination/grading is only possible
if the dropout or reset time is approximately the same. This is
for certain functions, such as overcurrent protection, ground
10
Fault locator (ANSI FL)
Futher Functions
Measured values
• Two-point method.
• Voltages V L1, V L2, V L3, V12, V 23, V 31
• Symmetrical components I1, I2, 3I0; V1, V 2, 3V0
• Power Watts, Vars, VA/P, Q, S
(P, Q: total and phase selective)
• Frequency
1
2
3
voltage values
4
indication.
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 7SJ81 can obtain and process metering pulses through an indication input. The metered values
can be displayed and passed on to a control center as an
accumulated value with reset. A distinction is made between
forward, reverse, active and reactive energy.
arc-chamber’s physical conditions into account when the CB
opens.
evolved which reflect the different operator philosophies. To
do justice to these, the relay offers several methods:
• ΣI
5
P1: Permissible
number of
operating cycles
at rated normal
current
6
P2: Permissible
number of
operating cycles
7
breaking current
8
Commissioning
• ΣI x , with x = 1..3
Test operation
• Σi2t.
9
10
for Low-Power CT and VT Applications – Application examples
Radial systems
1
General hints:
2
1) Auto-reclosure
(ANSI 79) only with
overhead lines
Infeed
2) Unbalanced load
faults
52
A
Busbar
52
3
I>t
IN>
t
I2>t
51
51N
46
2)
Busbar
*
4
5
C
52
I>t
IN>
t
I2>t
51
51N
46
Load
*
D
52
6
Load
I>t
IN>t
I2>t
51
51N
46
Load
7
Fig. 5/8 Protection concept with overcurrent protection
8
measurement of the
be made by a zerosequence low-power
current transformer
compensated systems
9
Infeed
Busbar
I>>
I>t
50
51
IN>t dir.
10
1)
67Ns
Load
Visio-LAS4840-us.pdf
52
Visio-LAS4839-us.pdf
Busbar
Ring-main cable
For lines with infeed from two sources, no selectivity can be achieved
with a simple definite-time overcurrent protection. Therefore, the
directional definite-time overcurrent
protection must be used. A nondirectional definite-time overcurrent
protection is enough only in the
corresponding busbar feeders. The
grading is done from the other end
respectively.
Advantage:
Disadvantage:
100% protection
of the line via
instantaneous
tripping, and easy
setting.
Infeed
1
Infeed
52
52
52
I>t
IN>t
ȣ>t
I2>t
51
51N
49
46
2
Overhead line
or cable 1
Overhead line
or cable 2
I>t
IN>t dir.
I>t
IN>t
67
67N
51
51N
52
Protection as in
the case of line
or cable 1
3
52
52
52
52
67
67N
51
51N
I>t
IN>t dir.
I>t
IN>t
Overhead line
or cable 3
Tripping times
increase towards
the infeed.
Overhead line
or cable 4
I>t
IN>t dir.
I>t
IN>t
67
67N
51
51N
4
52
Protection as in
the case of line
or cable 3
5
52
6
52
52
52
I>t
IN>t
ȣ>t
I2>t
51
51N
49
46
Load
Load
Visio-LSA4841-us.pdf
protection, 100% of the line can be
(ring-main cable).
7
8
9
10
1
Infeed
I>>t0
2
50/50N
52
51/51N
t0 = 50 ms
Busbar
52
52
52
I>>
I>t
I>>
I>t
I>>
I>t
50/50N
51/51N
50/50N
51/51N
50/50N
51/51N
4
5
6
7
drop.
8
9
Busbar
52
V<
f<
27
81U
I>, I>>,
I>>>
IN>>
I>, Ip
IN>,
INTOC
50
50N
51
51N
>
I2>
Final trip
79M
49
46
86
10
the overall system. The overcurrenttime protection functions are effective
only in the case of a short-circuit.
3
Automatic reclosing
Stage can
be blocked
52
1
than the fuse or
reclosing for
devices graduated
2
ON
52
52
TRIP
I>, I>>, I>>>
I>t, I>>t, Ip
50
Visio-LSA2219c-us.pdf
The auto-reclosure function (AR) has
starting and blocking options. In the
cycles. The overcurrent-time protection
is graded (stages I, Ip) according to the
grading plan. If an auto-reclosure function is installed in the incoming supply
of a feeder, first of all the complete
feeder is tripped instantaneously in case
of fault. Arc faults will be extinguished
independently of the fault location.
Other protection relays or fuses do
not trip (fuse saving scheme). After
successful auto-reclosure, all consumers
are supplied with energy again. If there
is a permanent fault, further reclosing
cycles will be performed. Depending on
the setting of the AR, the instantaneous
tripping stage in the infeed is blocked in
the first, second or third cycle, i.e., now
the grading is effective according to the
grading plan. Depending on the fault
location, overcurrent relays with faster
grading, fuses, or the relay in the infeed
will trip. Only the part of the feeder with
the permanent fault will be shut down
definitively.
51
IN>>
IN>t, IN>>t,
INTOC
50N
AR
51N
79
3
4
Fuse opens by
52
I>t, Ip
67
5
Fig. 5/13 Automatic reclosing
Infeed
A
Infeed
B
6
52
52
7
infeeds
67
67N
32R
67
67N
32R
8
52
52
52
Feeder
Feeder
Visio-LSA4116a-us.pdf
selectively shut down, so that supply to
the busbar is still possible through the
remaining infeed. To do this, directional
devices are required, which detect a
short circuit from the busbar towards the
infeed. In this context, the directional
time-overcurrent protection is normally
adjusted over the load current. Low-current faults cannot be shut down by this
protection. The reverse power protection
can be adjusted far below rated power,
and is thus also able to detect reverse
power in case of low-current faults far
below the load current. The reverse
power protection is implemented through
the “flexible protection functions”.
9
10
for Low-Power CT and VT Applications – Selection and ordering data
Description
1
Order No.
12345 6
7SJ81
Short code
7
3-
8 9 10 11 12 13 14 15 16
-3
17 18 19
–
Housing 1/6 19"; 4 x I, 3 BI, 5 BO (2 Changeover), 1 life contact
2
2
Housing 1/6 19"; 4 x I, 3 x V, 3 BI, 5 BO (2 Changeover), 1 life contact
3
4
Low Power Measuring Inputs
3
1
3
Auxiliary voltage
DC 24 V / 48 V
DC 60 V / 110 V / 125 V / 220 V / 250 V, AC 115 V / 230 V
1
5
Construction
4
E
Region DE, IEC, language German (language changeable)
Region World, IEC/ANSI, language English (language changeable)
5
A
B
6
No port
0
IEC 60870-5-103 or DIGSI 4/modem, electrical RS232
1
2
IEC 60870-5-103 or DIGSI 4/modem, optical 820 nm, ST connector
3
L 0
7
8
9
A
9
B
9
D
9
E
9
G
9
H
9
P
IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector
9
R
IEC 61850, 100 Mbit Ethernet, optical, double, LC connector
9
S
9
No Port
0
With Ethernet interface (DIGSI, not IEC 61850), RJ45 connector
6
10
3
for Low-Power CT and VT Applications – Selection and ordering data
Description
Order No.
Short code
12345 6 7
8 9 10 11 12 13 14 15 16 17 18 19
–
-3
7SJ81
Basic Functionality
50/51
50N/51N
50N(s)/51N(s)1)
49
74TC
50BF
46
37
86
FA
1
2)
2
Definite/Inverse time-overcurrent protection, phase I>, I >>, I>>>, Ip
Instantaneous/Inverse time-overcurrent protection, ground IE>, IE>>, IE>>>, IEp
Sensitive ground-current protection IEE>, IEE>>, IEEp
Overload protection
Undercurrent, underpower
Lockout
Inrush restraint
Basic functionality + Directional phase & ground overcurrent, directional sensitive ground fault,
voltage and frequency protection
67
Directional overcurrent protection phase I >,I >>, Ip
67N
Directional overcurrent protection ground IE>, IE>>, IEp
67Ns 1)
59N
27/59
81U/O
47
Directional sensitive ground fault protection IEE>, IEE>>, IEEp
Under/Overvoltage
Under/Overfrequency f<, f>
Phase rotation
Flexible protection functions (current and voltage parameters):
Protective function for voltage, power
power factor, frequency change
32/55/81R
3-
Automatic Reclosing (AR), Fault Locator (FL)
Without
79
With AR
FL 3)
With FL
79/FL 3)
With AR and FL
3
FC
4
3)
5
6
0
1
2
7
3
8
9
1) Depending on the connected low-power ground current transformer the function
will be either sensitive (INs) or non-sensitive (IN)
10
2) Only if position 6 = 1 or 2
3) Only if position 6 = 3 or 4
for Low-Power CT and VT Applications – Connection diagrams
2
F1
IA
F2
IB
F3
IC
F4
IN, INS
BO1
C11
C9
C10
BO2
C14
C13
C12
BO3
E1
E2
E3
E4
E5
E6
BO4
BO5
3
C3
C4
C5
C6
C7
C8
4
BI1
BI2
BI3
Life Contact
E 10
E8
E7
5
=
(~)
Power Supply
=
6
+
-
C1
C2
Port B
Port A
Ethernet interface
5_15_Visio-Figure-14-us.pdf
7
8
USB-DIGSI-Interface
Fig. 5/15 Connection diagram for SIPROTEC 7SJ811
9
10
B
A
250 V
1
F1
IA
F2
IB
F3
IC
F4
IN, INS
BO1
C11
C9
C10
BO2
C14
C13
C12
BO3
E1
E2
E3
E4
E5
E6
D9
D10
D11
D12
D13
D14
BO4
BO5
BO6
BO7
C3
C4
C5
C6
C7
C8
BI1
D1
D2
D3
D4
D5
D6
D7
D8
BI4
BO8
BI2
BI3
2
3
4
E10
E8
E7
Life Contact
=
BI5
1
(~)
Power Supply
=
+
-
5
C1
C2
BI6
Port B
Port A
Ethernet interface
USB-DIGSI-Interface
6
B
A
250 V
BI7
7
8
9
10
F1
IA
VA-N
IB
VB-N
IC
VC-N
IN, INS
F2
2
F3
F4
BO1
C11
C9
C10
BO2
C14
C13
C12
BO3
E1
E2
E3
E4
E5
E6
BO4
BO5
3
C3
C4
C5
C6
C7
C8
4
BI1
BI2
BI3
E10
E8
E7
Life Contact
5
=
(~)
Power Supply
=
6
+
-
C1
C2
Port B
Port A
Ethernet interface
7
8
USB-DIGSI-Interface
9
10
B
A
250 V
1
F1
IA
VA-N
IB
VB-N
IC
VC-N
IN, INS
F2
F3
F4
BO1
C1 1
C9
C10
BO2
C14
C13
C12
BO3
E1
E2
E3
E4
E5
E6
D9
D10
D11
D12
D13
D14
BO4
BO5
BO6
BO7
C3
C4
C5
C6
C7
C8
BI1
D1
D2
D3
D4
D5
D6
D7
D8
BI4
BO8
BI2
1
2
3
4
BI3
E10
E8
E7
Life Contact
=
BI5
(~)
Power Supply
=
+
-
5
C1
C2
BI6
Port B
Port A
Ethernet interface
Visio-Figure-17-us.pdf
USB-DIGSI-Interface
6
B
A
250 V
BI7
7
8
9
10
for Low-Power CT and VT Applications – Connection example
Standard connection capabilities
52
52
52
Flush Mounting Housing
F1
F2
2
F3
F4
LPCT LPCT LPCT
A
B
IA
IB
IC
IN
C
SIPROTEC
3
5_19_Visio-SIP0023us.pdf
1
Fig. 5/19 Connection to three low power CTs, normal circuit layout - appropriate for
all networks
4
52
52
52
F1
F2
6
F3
F4
LPCT LPCT LPCT
7
A
B
C
IA
IB
IC
IN
SIPROTEC
5_20_Visio-SIP0023us.pdf
5
LPCT
8
Fig. 5/20 Connection to 3 low-power CTs - additional low-power CT for sensitive
ground fault detection INS - only for isolated or compensated
networks
9
10
52
52
1
52
LPCT/LPVT
R2
F1
*
1)
*
R1
*
VA-N
IA
2
LPCT/LPVT
R2
F2
*
1)
*
R1
*
VB-N
IB
3
LPCT/LPVT
R2
F3
4
VC-N
IC
*
A
B
F4
C
IN
SIPROTEC
LPCT
*
1)
*
*
R1
5
6
1) R1 and R2 represent the primary voltage divider.
Important! Cable Shield Grounding must be done on the Cable Side!
Fig. 5/21 Connection for combined low-power current and voltage
transformers in phase L1, L2 and L3
7
8
9
10
52
52
52
LPVT
R2
1)
*
R1
Flush Mounting
Housing
RJ45 Y-Cable
*
1
F1 VA-N
IA
2
LPVT
R2
RJ45 Y-Cable
*
1)
*
R1
F2 VB-N
IB
LPVT
R2
*
1)
RJ45 Y-Cable
*
3
R1
4
A
*
*
*
LPCT
LPCT
LPCT
B
F4
C
F3 VC-N
IC
IN
SIPROTEC
5
*
LPCT
6
Fig. 5/22 Connection to low-power transformers for 3 phase currents,
sensitive ground current INS and 3 phase-to-ground-voltages.
The LPCT and the LPVT are connected to SIPROTEC 7SJ81 through
a Y-cable (refer to Fig. 2/23)
7
To 7SJ81/7SK81
RJ45 plug
8
7
6
5
4
3
2
1
8
1)
1)
9
8
10
7
6
5
4
3
2
1
8
7
6
5
4
3
2
RJ45 socket
RJ45 socket
From low-power VT
(Voltage divider)
From low-power CT
1) The connections 5, 6, 7 and 8 are optional, but not mandatory.
Fig. 5/23 Y-cable for a connection of LPCT and LPVT with SIPROTEC 7SJ81
Bild 5/23 Y-Kabel für eine Verbindung von LPCT und LPVT mit 7SJ81
1
5_23_Visio-Y-cable_us.pdf
1)
1)
Generator and Motor Protection 7SK80
SIPROTEC Compact
Page
1
2
3
4
Description
6/3
Function overview
6/4
Applications
6/5
Application sheets
6/6
6/12
6/16
Connection diagrams
6/18
Connection examples
6/24
Connection types
6/27
5
6
7
8
9
10
Description
Description
The SIPROTEC 7SK80 is a multi-functional motor protection
1
The SIPROTEC 7SK80 features “flexible protection functions”.
the user.
2
7SK80_W3_de_en.psd
Therefore protection of change for frequency or reverse
power protection can be realized, for example.
The relay provides circuit-breaker control, further switching
devices and automation functions. The integrated programmable logic (CFC) allows the user to add own functions, e.g.
for the automation of switchgear (interlocking). The user is
also allowed to generate user-defined messages.
3
Highlights
4
using DIGSI
5
Fig. 6/1 SIPROTEC 7SK80 front view
• 6-line display
• USB front port
6
Ethernet rings
7
IEC 61850 GOOSE
LSP3.01-0008.eps
Ethernet with SNTP (over Port A or Port B)
• Number of binary binputs and inary outputs by connection from up to two SICAM I / O-Units extendable.
8
9
Fig. 6/2 SIPROTEC 7SK80 rear view
10
Function overview
1
2
IEC
ANSI
Definite and inverse time-overcurrent protection (phase / ground)
I>, I>>, I>>>, IE>, IE>>, IE>>>; Ip, IEp
50, 50N; 51, 51N
Directional time-overcurrent protection, ground
67N
Directional overcurrent protection, ground (definite / inverse)
IEE>, IEE>>, IEEp
67Ns, 50Ns
Displacement voltage, zero-sequence voltage
V E, V 0>
59N
AKU
74TC
I<
37
ϑ>
49
Temperature monitoring
3
38
Load jam protection
51M
14
IIE>
IIEdir>
Overcurrent protection, voltage controlled
4
5
6
7
8
66 / 86
Undervoltage / overvoltage protection
V<, V>
27 / 59
P<>, Q<>
32
Power factor
cos ϕ
55
Overfrequency / underfrequency protection
f<, f>
81O / U
50BF
I 2>
46
Unbalance-voltage protection and / or phase-sequence monitoring
V2>, phase sequence
47
Start-time supervision
48
Lockout
86
df / dt
81R
dU / dt
27R, 59R
Table 6/1 Funktionsübersicht
(isolators / isolating switches)
• System / service interface
–
–
–
–
–
–
–
–
IEC 61850 Edition 1 and 2
IEC 60870-5-103 and IEC 60870-5-104
PROFIBUS-DP
DNP 3.0
MODBUS RTU
DNP3 TCP
PROFINET
Ethernet redundancy protocols RSTP, PRP and HSR
• Ethernet interface for DIGSI 4, and extension from up to
two SICAM I / O-Units 7XV5673 as well as a RTD box
• Trip-circuit supervision
• 8 oscillographic fault records
10
51V
Restart inhibit
9
67Ns
• Motor statistics.
ATEX100-certification
The Device is available with ATEX100-certification for
protection of explosion-proved machines of increasedsafety type ”e“
Hardware
• 0 / 3 voltage transformers
• 3 / 7 binary inputs (thresholds configurable using
software)
• 5 / 8 binary outputs (2 changeover)
• 0 / 5 RTD inputs
• 1 life contact
Applications
are stored in the relay to provide the user or operator with
all the key data required to operate modern substations.
The SIPROTEC 7SK80 unit is a numerical motor protection
relay that can perform control and monitoring functions and
therefore provide the user with a cost-effective platform for
power system management, that ensures reliable supply of
electrical power to the customers. The ergonomic design
makes control easy from the relay front panel. A large, easyto-read display was a key design factor.
Motor protection
The SIPROTEC 7SK80 device is specifically designed to
protect induction-type asynchronous motors.
Line protection
Control
1
2
SIPROTEC 7SK80 units can be used for line protection
of high and medium-voltage networks with grounded,
point.
The integrated control function permits control of disconnect devices, grounding switches or circuit-breakers through
Programmable logic
The SIPROTEC 7SK80 device provides all the functions for
backup protection for transformer differential protection.
The inrush suppression effectively prevents unwanted trips
that can be caused by inrush currents.
Backup protection
As a backup protection the SIPROTEC 7SK80 devices are
Switchgear cubicles for high / medium voltage
of high / medium-voltage applications. In general, no separate
measuring instruments (e.g., for current, voltage, frequency,
…) or additional control components are necessary.
3
4
5
6
Busbar
52
CFC logic
Commands/Feedbacks
Limits
86
AND
min/max-memory
Esc
RS232/485/FO/
Ethernet
IEC 60870-5-103/4
IEC 61850
PROFIBUS-DP
DNP 3.0
MODBUS RTU
DNP3 TCP
PROFINET
...
Enter
7
8
9
4
1
5
2
6
3
Fn 0
.
RTD-Box
V, f, P
I, V, P, Q,
cos ˳, f
Mean value
Lock out
Operation
7
P<>, Q<> cos˳ df/dt dV/dt
Additional motor protection
I<
Fault recording
66/86
14
37
Load Jam
48
32
55
81R
f<, f>
V>
V<
81U/O
59
27
8
27R
59R
Directional supplement (Ground)
51M
Jammed rotor protection
47
9
Phase sequence
Motor statistics
38
Storage temperature
IN>, IN>>, IN-TOC
I>, I>>,
I>>>
50
ITO
C
51
ININ>, IN>>, TO
C
IN>>>
50N
51N
I2>
46
!
49
BF
InRush
BLK
Intermitt.
ground fault
50BF
51V
fault protection
INs>,
INs>>
50N
67Ns
51N
IN>, IN>>, IN-TOC
IN>>>
66/86 Motor restart inhibit
48 Motor starting protection
! Thermal overload protection
67NsTOC
67NsTOC
VN>
59N
67N
10
Application sheets
1
2
3
4
5
Directional overcurrent protection, ground (ANSI 67N)
Directional ground protection is a separate function.
It operates in parallel to the non-directional ground
overcurrent elements. Their pickup values and delay times
can be set separately. Definite-time and inverse-time
characteristics aroffered. The tripping characteristic can be
rotated by 0 to ± 180 degrees.
can also be selected and activated. The inverse-time
function provides – as an option – voltage-restraint or
voltage-controlled operating modes
For ground protection, users can choose whether the
direction is to be calculated using the zero-sequence or
negative-sequence system quantities (selectable). If the
zero-sequence voltage tends to be very low due to the zerosequence impedance it will be better to use the negativesequence quantities.
using the reset characteristic (disk emulation), the 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 (disk
emulation).
6
IEC 60255-3
ANSI / IEEE
Inverse


Short inverse
Long inverse


Moderately inverse
7


Very inverse


Extremely inverse


8
9
Inrush restraint
If second harmonic content is detected during the energization of a transformer, the pickup of stages I>, Ip, I> ger and
Ip ger is blocked.
10
Fig. 6/4 Directional characteristic of the directional time-overcurrent
protection, ground
(ANSI 59N / 64, 67Ns, 67N)
For isolated-neutral and compensated networks, the
direction of power flow in the zero sequence is calculated
from the zero-sequence 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 low-resistance grounded networks
with ohmic-inductive current, the tripping characteristics
can be rotated approximately ± 45 degrees (see Fig. 6 / 5).
Application sheets
The normal ground fault protection is not capable of reliably
detecting and clearing the sometimes very short current
pulses. The required selectivity for intermittent ground faults
is achieved by summing up the times of the individual pulses
and tripping after a (programmable) summation time has
been reached. The pickup threshold Iie> evaluates RMS values
referred to 1 system period.
Directional intermittent ground fault protection (ANSI 67Ns)
1
2
The directional intermittent ground fault protection function
has the task to selectively detect intermittent ground faults in
resonant-grounded cable networks.
Intermittent ground faults in resonant-grounded cable
networks are typically marked by the following properties:
– Very short high-current ground current impulse (up to
several hundred amperes) with a duration of less than 1
ms.
– They are self-extinguishing and reignite – depending on
the network conditions and fault characteristics – within a
half period up to several periods.
• TRIP via the displacement voltage V E
non-directional
(ANSI 50Ns, 51Ns / 50N, 51N)
Intermittent (re-igniting) faults are caused by poor cable
insulation or water ingress into cable joints. After some time,
the faults extinguish automatically or they develop into
permanent short circuits. During the intermitting, neutral
point resistances in impedance grounded systems can suffer
thermal overload.
– They can also develop into static faults over prolonged
periods of time (many seconds up to minutes).
Such intermittent ground faults are typically caused by poor
insulation, e.g. due to insufficient water insulation of old
cables.
Ground fault functions based on measured values of the
fundamental component are primarily designed for detection of static ground faults and they do not always show a
correct behavior in the case of intermittent ground faults.
The directional intermittent ground fault protection function
evaluates specifically the ground current impulses and for
the direction determination it refers them to zero voltage.
the two-element phase-balance current / negative-sequence
protection detects high-resistance phase-to-phase faults and
phase-to-ground faults on the low side of a transformer (e.g.
Dy 5). This function provides backup protection for highresistance faults through the transformer.
another trip command can be initiated using the breaker
failure protection which trips the circuit-breaker of an
upstream feeder. Breaker failure is detected if, after a trip
command is issued and the current keeps on flowing into the
faulted circuit. It is also possible to make use of the circuitbreaker position contacts (52a or 52b) for indication as
opposed to the current flowing through the circuit-breaker.
3
4
5
6
7
8
9
10
Application sheets
2
3
SIPROTEC 7SK80 enables the user to easily add up to 20
additional protection functions. Parameter definitions are
under and overvoltage). All stages operate with protection
priority or speed.
circuit-breaker trip coil including its incoming cables.
An alarm signal is generated whenever the circuit is
interrupted.
Current
4
5
6
7
8
9
Voltage
Measured-value
processing
I measured
V measured
3I0, I1, I2
3V0, V1, V2
34
FRV˳
f
df/dt
dV/dt
Parameter
Time
t
Pickup
TRIP
command
Threshold
Function 1
Function 2
Function 20
Visio-flexProFunc-us.pdf
1
Lockout (ANSI 86)
key is used to reset the lockout state. The lockout state is
also stored in the event of supply voltage failure. Reclosure
can only occur after the lockout state is reset.
function with an integrated warning / alarm element for
Protection of motors requires an additional time constant.
This is used to accurately determine the thermal heating of
the stator during the running and motor stopped conditions
Protection functions / stages available are based on the available measured analog quantities:
Function
ANSI
I>, IE>
50, 50N
The ambient temperature or the temperature of the coolant
can be detected either through internal RTD inputs or via an
external RTD-box.
The thermal replica of the overload function is automatically
adapted to the ambient conditions.If neither internal RTD
inputs nor an external RTD-box exist,
it is assumed that the ambient temperatures are constant.
U<, U>, UE>
27, 59, 59N
3I0>, I1>, I2>, I2 / I1>, 3U0>, V1> <, V2 > <
50N, 46, 59N, 47
P> <, Q> <
32
cos ϕ
55
f><
81O, 81U
If the relays are used in conjunction with electromechanical relays, in networks with intermittent faults, the long
dropout times of the electromechanical relay (several
hundred milliseconds) can lead to problems in terms of time
coordination / grading. Proper time coordination / grading
is only possible if the dropout or reset time is approximately
the same. This is why the parameter for dropout or reset
times can be defined for certain functions, such as
overcurrent protection, ground short-circuit and phasebalance current protection.
df / dt > <
81R
dV / dt> <
27R, 59R
• Rate-of-voltage-change protection (ANSI 27R, 59R).
10
Application sheets
Motor protection
1
Restart inhibit (ANSI 66 / 86)
If a motor is subjected to many successive
starts, the rotor windings or rotor bars can
be heated up to a point where the electrical
connections between the rotor bars and the
end rings are damaged. As it is not possible
to physically measure the heat of the rotor
we need to determine the heat by measuring the current the rotor is drawing through
the stator to excite the rotor. A thermal
replica of the rotor is established using a I2t
curve. The restart inhibit will block the user
from starting the motor if the relay determined that the rotor reached a temperature
that will damage the rotor should a start be
attempted. The relay will thus only allow a
restart if the rotor has a sufficient thermal
reserve to start (see Fig. 6/7).
Emergency start-up
If the relay determines that a restart of the
motor is not allowed, the relay will issue
a block signal to the closing command,
effectively blocking any attempt to start the
motor. The emergency startup will defeat
this block signal if activated through a
binary input. The thermal replica can also be
reset to allow an emergency restart of the
motor.
Temperature monitoring (ANSI 38)
2
3
T - TRIP
[s]
I STARTUP
Motor startup current
T max STARTUP cold
max. startup time of motor with
startup current from cold motor
T max STARTUP warm
max. warm motors startup times
I Pickup
Threshold of the function
5
6
T max STARTUP cold
T max STARTUP warm
4
Cold Motor
Warm Motor
I
I Pickup
I STARTUP
Either 5 internal RTD inputs or up to 12 RTD
inputs through an external RTD box can be
applied for temperature detection. Example Fig. 6/7 Starting time supervision characteristics
for the application with 5 internal RTD
I A2
tAmax
tTRIP
inputs: Two RTDs can be applied to each bearing (the cause
I
of 50 % of typical motor failures).
= Tripping time
The remaining RTD is used to measure the ambient tempera- tTRIP
=
Motor starting current
I
ture. Stator temperature is calculated by the current flowing
A
= Max. permissible starting time
t Amax
through the stator windings. Alternatively up to 12 RTDs
I
= Actual current flowing
can be applied using an external RTD box connected either
through RS485 on Port B or through Ethernet on Port A.
Because the flow of current is the cause of the heating of
The RTDs can also be used to monitor the thermal status of
the motor windings, this equation will accurately calculate
transformers or other pieces of primary equipment.
the starting supervision time. The accuracy will not be
affected by reduced terminal voltage that could cause a
Starting time supervision / Locked rotor protection
prolonged start. The trip time is an inverse current depen(ANSI 48 / 14)
dant characteristic (I2t).
Starting time supervision protects the motor against
Block rotor can also be detected using a speed sensor
unwanted prolonged starts that might occur in the event
connected to a binary input of the relay. If activated it will
of exces-sive load torque or excessive voltage drops within
cause an instantaneous trip.
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:
7
8
9
10
Application sheets
1
2
Load jam protection (ANSI 51M)
Frequency protection (ANSI 81O / U)
Load jam is activated when a sudden high load is applied
to the motor because of mechanical failure of a pump for
example. The sudden rise in current is detected by this
function and can initiate an alarm or a trip. The overload
function is too slow and thus not suitable
60 Hz)). There are four elements (individually set as overfrequency, underfrequency or OFF) and each element can be
delayed separately. Blocking of the frequency protection
Unbalanced-load protection (ANSI 46)
The unbalanced load protection detects a phase failure or
load unbalance due to system asymmetry, and protects the
rotor from impermissible overheating.
3
Motor statistics
4
Essential statistical information is saved by the relay during
a start. This includes the duration, current and voltage. The
relay will also provide data on the number of starts, total
operating time, total down time, etc. This data is saved as
statistics in the relay.
5
6
7
9
Additional functions, which are not time critical, can be
implemented using the CFC measured values. Typical
functions include reverse power, voltage controlled overcurrent, phase angle detection, and zero-sequence voltage
detection.
Further functions
Measured values
positive phase-sequence or negative phase-sequence
voltage. Three-phase and single-phase connections are
possible.
and reactive power. The following functions are available
for measured value processing:
• Voltages V L1, V L2, V L3, V12, V 23, V 31
• Symmetrical components I1, I2, 3I0; V1, V 2, 3V0
continues to work, however, with decrease accuracy. The
8
• Power Watts, Vars, VA / P, Q, S (P, Q: total and phase
selective)
• Frequency
voltage values
indication
10
Application sheets
Metered values
available, the 7SK80 can obtain and process metering pulses
through an indication input. The metered values can be
displayed and passed on to a control center as an accumulated value with reset. A distinction is made between
Expansion of the binary inputs and outputs with
SICAM I / O Unit 7XV5673
To expand binary inputs and outputs, up to two SICAM I / O
Units 7XV5673 can be connected to the SIPROTEC 7SK80.
Every SICAM I / O Unit 7XV7653 has 6 binary inputs, 6
binary outputs and one ethernet switch for cascading. The
connection to the protection device is established either via
the DIGSI Ethernet service interface Port A or via IEC 61850
GOOSE to Port B (system interface with EN100 module).
Circuit-breaker wear monitoring /
There is no exact mathematical method to calculate the
wear or the remaining service life of a circuit-breaker that
takes arc-chamber’s physical conditions into account when
the CB opens.
• ΣI
• ΣI x , with x = 1..3
• Σi2t.
1
2
of operating cycles
at rated normal
current
of operating cycles
4
breaking current
5
Commissioning
to prevent unnecessary data from being transmitted.
During commissioning, all indications with test tag for test
purposes can be connected to a control and protection
system.
Test operation
below or exceeds the limit value during determination of
the remaining service life.
3
6
7
8
9
10
Radial systems
General hints:
1
2
1) Unbalanced load
faults
Infeed
A
52
Busbar
52
3
I>t
IN>t
I2>t
51
51N
46
1)
Busbar
*
4
5
C
52
I>t
IN>t
I2>t
51
51N
46
Load
Busbar
D
52
6
Load
7
I>t
IN>t
I2>t
51
51N
46
Load
8
compensated systems
9
measurement of the
earth current should be
made by core balance
current transformer
Infeed
Busbar
7XR96
1)
60/1
10
I>>
I>t
50
51
IN>t dir.
67Ns
6_10_LSA4840-us.pdf
52
Load
6_9_LSA4839-us.pdf
*
Anwendungsbeispiele
Applicable, with effective and
low-resistance infeed (IE ≥ IN, Motor),
to low-voltage motors and highvoltage motors with low-resistance
infeed (IE ≥ IN, Motor)
52
I>, I>>,
I>>>
IN>t
>
IStart²t
I2>
50
51N
49
48
46
1
6_11_LSA4869-us.pdf
Small and medium-sized
motors < 1MW
2
M
Fig. 6/11 Protection concept for small sized motors
High-resistance infeed
(I E ≤ I N, Motor)
52
2) The sensitive directional earthfault detection (ANSI 67Ns) is only
applicable with the infeed from an
isolated system or a system earthed
via Petersen coil.
7XR96
1)
60/1 A
I>>
>
IStart²t
50
49
48
46
IN>t
2)
51N
67Ns
3
I<
37
6_12_LSA4870-us.pdf
1) Zero-sequence current transformer
461
PU
M
4
5
Fig. 6/12 Protection concept for medium sized motors
Busbar
Medium-voltage
Generators < 500 kW
If a zero-sequence current transformer is available for the sensitive
earth-fault protection, the SIPROTEC
7SK80 relay with the sensitive earthcurrent input should be used.
6
G
I>t
IN>t
46-1
PU
51/51N
46
6_13_LSA4871-us.pdf
52
49
7
8
Fig. 6/13 Protection concept for smallest generators with solidly earthed neutral
Busbar
Medium-voltage
9
G1
Generator
2
*
RN =
I>t
IN>t
46-1
PU
51/51N
46
49
6_14_LSA4872-us.pdf
52
VNom
3 · (0.5 to 1) · INom
10
Fig. 6/14 Protection concept for smallest generators with low-resistance neutral earthing
Generators up to 1MW
Two voltage transformers in
V-connection are sufficient.
1
Busbar
52
2
f><
81
G
51
P>
46-1 PU
49
46
V>
32
6_15_LSA4873-us.pdf
I>t
59
IN>t
3
51N
4
Fig. 6/15 Protection concept for small generators
5
Infeed
I>>t0
50/50N
6
52
51/51N
t0 = 50 ms
Busbar
7
8
52
52
I>, I>>,
I>>>
I>t
I>, I>>,
I>>>
I>t
I>, I>>,
I>>>
I>t
50/50N
51/51N
50/50N
51/51N
50/50N
51/51N
Fig. 6/16 Busbar protection with reverse interlocking
10
In unstable power systems (e.g.
solitary systems, emergency power
supply in hospitals), it may be necessary to isolate selected consumers
from the power system in order
to protect 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.
Busbar
52
V<
f<
27
81U
I>, I>>,
I>>>
IN>>
I>, Ip
IN>,
INTOC
50
50N
51
51N
>
I2>
Final trip
49
46
86
6_17_LSA4876-us.pdf
9
6_16_LSA4842-us.pdf
52
Busbar
High-voltage
1
59-1 PU ,t
59
52
TRIP
I>, I>>
I>t, I>>t, Ip
>t
I2>t, I2>>t
50
51
49
46
IN>, IN>>
IN>t, IN>>t,
INTOC
50N
51N
2
The high-current stage enables a
current grading, the overcurrent
stages work as backup protection to
subordinate protection devices, and
the overload function protects the
transformer from thermal overload.
Low-current, single-phase faults
on the low-voltage side, which are
reproduced in the opposite system on
the high-voltage side, can be detected
with the unbalanced load protection.
The available inrush blocking prevents
pickup caused by the inrush currents
of the transformer.
Inrush blocking
3
87
*
e.g.
7UT61
IN>, IN>>
IN>t, IN>>t,
INTOC
50N
51N
4
52
Busbar
Medium-voltage
52
52
52
TRIP
52
5
I2>>t, I2>t
46
typical Feeder
6
Unbalanced fault
7
Motor protection
The undervoltage function prevents
a start when the voltage is too low;
the overvoltage function prevents
insulation damages.
8
Busbar
52
Rotation
V<
V>
V0>
47
27
59
59N
I>, I>>,
I>>>
S>
46-1 PU
I<
ILoad>
50
49
46
37
51M
14
Blocked rotor
49
Motor starting protection
86
Motor restart inhibit
IN>>
IN>
51N
Tachometer
M
or
67N
9
For short-circuit protection, the
stages I>> and IE >> are available, for
example. Sudden load variations in
running operation are acquired by the
Iload> function. For isolated systems,
the sensitive earth-fault detection
(IEE>>, V0 >) can be used. The stator is
protected against thermal overload by
υs, the rotor by I2>, start-time supervision and restart inhibit. A locked
rotor is detected via a binary input,
and shut down as fast as required. The
restart inhibit can be deactivated by
an “emergency start”.
10
Fig. 6/19 Typical protection concept for an asynchronous high-voltage motor
Product description
Order No.
Short code
12345 6 7
1
Motor Protection 7SK80 V4.7
8 9 10 11 12 13 14 15 16 17 18 19
-
7SK80
-
+
2
Housing 1/6 19"; 4 x I, 3 BI, 5 BO (2 Changeover / Form C), 1 life contact
1
Housing 1/6 19"; 4 x I, 7 BI, 8 BO (2 Changeover / Form C), 1 life contact
2
Housing 1/6 19"; 4 x I, 3 x V, 3 BI, 5 BO (2 Changeover / Form C), 1 life contact
3
Housing 1/6 19"; 4 x I, 3 x V, 7 BI, 8 BO (2 Changeover / Form C), 1 life contact
4
Housing 1/6 19"; 4 x I, 3 BI, 5 BO (2 Changeover / Form C), 5 RTD inputs, 1 life contact
5
Housing 1/6 19"; 4 x I, 3 x V, 3 BI, 5 BO (2 Changeover / Form C), 5 RTD inputs, 1 life contact
6
see
next
page
Measuring inputs, default settings I
3
Iph = 1 A / 5 A, Ie = 1 A / 5 A
1
Iph = 1 A / 5 A, Iee (sensitive) = 0.001 to 1.6 A / 0,005 bis 8 A
2
Auxiliary voltage
4
24 V to 48 V
1
DC 60 V to 250 V; AC 115 V; AC 230 V
5
Construction
5
Surface-mounting case, screw-type terminal
B
Flush-mounting case, screw-type terminal
E
Region specific default and language settings
Region DE, IEC, language German (language changeable), standard front
Region World, IEC / ANSI, language English (language changeable), standard front
Region US, ANSI, language US-English (language changeable), US front
Region FR, IEC / ANSI, language French (language changeable), standard front
Region World, IEC / ANSI, language Spanish (language changeable), standard front
Region World, IEC / ANSI, language Italian (language changeable), standard front
Region RUS, IEC / ANSI, language Russian (language changeable), standard front
Region CHN, IEC / ANSI, language Chinese (language changeable), chinese front
6
A
B
C
D
E
F
G
K
7
8
9
10
No port
IEC 60870-5-103 or DIGSI 4 / Modem, electrical RS232
IEC 60870-5-103 DIGSI 4 / Modem or RTD-box, electrical RS485
IEC 60870-5-103 DIGSI 4 / Modem or RTD-box, optical 820 nm, ST connector
DNP3 TCP + IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector
DNP3 TCP + IEC 61850, 100 Mbit Ethernet, optical, double, LC connector
PROFINET + IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector
PROFINET + IEC 61850, 100 Mbit Ethernet, optical, double, LC connector
IEC 60870-5-104 + IEC 61850, 100Mbit Ethernet, electrical,double, RJ45 connector
0
1
2
3
9
9
9
9
9
9
9
9
9
9
9
L 4 R
IEC 60870-5-104 + IEC 61850, 100Mbit Ethernet, optical, double, LC connector
9
L 4 S
9
9
9
No port
0
With Ethernet interface (DIGSI, RTD-box, I / O-Unit, not IEC 61850), RJ45 connector
6
With fault recording
1
With fault recording, average values, min / max values
3
L
L
L
L
L
L
L
L
L
0
0
0
0
0
0
0
0
0
A
B
D
E
G
H
P
R
S
L
L
L
L
2
2
3
3
R
S
R
S
ANSI No.
Product description
Bestell-Nr.
Short code
Order No.
12345 6 7
Motor Protection 7SK80 V4.7
7SK80
8 9 10 11 12 13 14 15 16 17 18 19 20
-
49
74TC
50BF
46
86
48
37
66 / 86
14
51M
1
+
H D 0
Basic functionality (contained in all options)
50 / 51
50N / 51N
50N(s) / 51N(s)1)
-
4)
Overcurrent protection phase I>, I>>, I>>>, Ip
Overcurrent protection ground I E >, I E >>, I E >>>, I Ep
Sensitive ground fault protection I EE >, I EE >>, I EEp
Overload protection
Circuit breaker failure protection
Lockout
Starting time supervision
Restart inhibit
Load jam protection
Motor statistics
Inrush restraint
2
3
4
Basic functionality + Directional sensitive ground fault, voltage and frequency
protection + Directional intermittent ground fault protection
H E 0
5)
5
51V
67N
67Ns1)
67Ns2)
64 / 59N
27 / 59
81 U / O
47
Directional overcurrent protection ground, I E >, I E >>, I E >>>, I Ep
Directional sensitive ground fault protection, I EE >, I EE >>, I EEp
Under / Overvoltage
Under / Overfrequency, f<, f>
Phase rotation
Flexible protection functions (current and voltage parameters):
27R / 32 / 55 / 59R / 81R Protection function for voltage, power, power factor,
rate-of-frequency change, rate-of-voltage change,
6
7
ATEX100-certification
with ATEX100-certifi cation
3)
for protection of explosion-proved machines of increased-safety type ”e“
Z X 9 9
8
9
1) Depending on the ground current input the function will be either sensitive (IEE ) or non-sensitive (IE ).
2) Function only available with sensitive ground current input (Position 7 = 2)
10
3) If no ATEX100-certification is required, please order without the order No. extension -ZX99
Connection diagrams
1
IA
F1
F2
F3
F4
F5
F6
F7
F8
C11
C9
C10
BO2
C14
C13
C12
BO3
E1
E2
E3
E4
E5
E6
IC
I N, INS
BO4
3
BO5
4
C3
C4
C5
C6
C7
C8
5
BI1
BI2
BI3
Life Contact
E10
E8
E7
=
(~)
Power Supply
=
6
+
-
C1
C2
Port B
7
Port A
Ethernet interface
USB-DIGSI-Interface
6_20_LSA4784-us.ai
8
Fig. 6/20 Motor protection SIPROTEC 7SK801
9
10
B
A
250 V
2
I B, IN2
BO1
Connection diagrams
1
IA
F1
F2
F3
F4
F5
F6
F7
F8
I B, IN2
BO1
C11
C9
C10
BO2
C14
C13
C12
BO3
E1
E2
E3
E4
E5
E6
D9
D10
D11
D12
D13
D14
IC
I N, INS
BO4
BO5
BO6
BO7
C3
C4
C5
C6
C7
C8
BI1
D1
D2
D3
D4
D5
D6
D7
D8
BI4
BO8
BI2
BI3
3
4
E10
E8
E7
Life Contact
=
BI5
2
(~)
Power Supply
=
+
-
5
C1
C2
6
BI6
Port B
Port A
Ethernet interface
6_21_LSA4785-us.ai
USB-DIGSI-Interface
B
A
250 V
BI7
7
8
9
10
Connection diagrams
1
IA
F1
F2
F3
F4
F5
F6
F7
F8
4
I N, INS
C14
C13
C12
BO3
E1
E2
E3
E4
E5
E6
BO4
VA, VAB
VB, VBC
BO5
VC, VN, VX
C3
C4
C5
C6
C7
C8
5
BO2
IC
E9
E11
E12
E13
E14
3
C11
C9
C10
BI1
BI2
BI3
E10
E8
E7
Life Contact
=
(~)
Power Supply
=
6
+
-
C1
C2
Port B
Port A
Ethernet interface
7
6_22_LSA4874a-en.ai
USB-DIGSI-Interface
8
9
10
B
A
250 V
2
I B, IN2
BO1
Connection diagrams
1
IA
F1
F2
F3
F4
F5
F6
F7
F8
I B, IN2
BO1
C11
C9
C10
BO2
C1 4
C13
C12
E1
E2
E3
E4
E5
E6
D9
D10
D11
D12
D13
D14
2
E10
E8
E7
5
IC
BO3
I N, INS
BO4
E9 Q2
E11
E12
E13
E14
VA, VAB
VB, VBC
VC, VN, VX
BO5
BO6
BO7
C3
C4
C5
C6
C7
C8
BI1
D1
D2
D3
D4
D5
D6
D7
D8
BI4
BO8
BI2
BI3
Life Contact
=
BI5
(~)
Power Supply
=
+
-
3
4
C1
C2
6
BI6
Port A
Ethernet interface
6_23_LSA4875-us.ai
USB-DIGSI-Interface
B
A
7
250 V
BI7
Port B
8
9
10
Connection diagrams
1
IA
F1
F2
F3
F4
F5
F6
F7
F8
C11
C9
C10
BO2
C1 4
C13
C12
BO3
E1
E2
E3
E4
E5
E6
IC
I N, INS
BO4
3
BO5
4
C3
C4
C5
C6
C7
C8
5
BI1
E10
E8
E7
Life Contact
BI2
=
BI3
(~)
Power Supply
=
+
C1
C2
-
Port B
(+)
(-)
7
D1
D2
D5
D3
D4
(+)
(-)
D7
D8
D6
(+) D9
(-) D10
8
(+) D11
(-) D12
D13
9
RTD1
COMP12
Port A
Ethernet interface
A
USB-DIGSI-Interface
RTD2
RTD3
COMP34
RTD4
RTD5
COMP5
D14
*)
10
6_24_LSA4823-us.ai
6
(+)
(-)
B
Interference Suppression Capacitors at the
Relay Contacts, Ceramic, 2.2 nF, 250 V
2
I B, IN2
BO1
Connection diagrams
1
E9
E11
E12
E13
E14
C3
C4
C5
C6
C7
C8
IA
I B, IN2
BO1
C11
C9
C10
BO2
C1 4
C13
C12
2
BO3
E1
E2
E3
E4
E5
E6
3
E10
E8
E7
4
IC
I N, INS
BO4
VA, VAB
VB, VBC
BO5
VC, VN, VX
BI1
Life Contact
BI2
=
BI3
(~)
Power Supply
=
+
C1
C2
-
Port B
(+)
(-)
D1
D2
D5
D3
D4
(+)
(-)
D7
D8
D6
(+) D9
(-) D10
(+) D11
(-) D12
D13
D14
RTD1
COMP12
Port A
Ethernet interface
USB-DIGSI-Interface
RTD2
RTD3
COMP34
RTD4
RTD5
COMP5
*)
6
A
6_25_LSA4824-us.ai
(+)
(-)
5
B
F1
F2
F3
F4
F5
F6
F7
F8
7
8
9
10
Connection examples
Standard connection
circuit.
2
52
52
52
P2
S2
P1
S1
F1
IA
F2
F3
IB
F4
F5
IC
F6
IN
F7
F8
SIPROTEC
3
6_26_LSA4826us.pdf
1
A
B
C
M
4
A
B
C
A
B
b
5
a
6
52
52
52
VB-N
E12
E13
VC-N
E14
IA
F1
7
l
K
k
F4
IC
F5
L
F2
IB
F3
F6
IN
F7
F8
SIPROTEC
M
8
Fig. 6/27 Residual current circuit with directional element for ground
(non directional element for phases)
A
B
C
9
52
52
F1
F3
F5
10
L
l
K
k
A
B
C
L
l
K
k
F8
IA
IB
IC
INs
SIPROTEC
F2
F4
F6
F7
6_28_LSA4790us.pdf
52
Fig. 6/28 Current transformer connections on three current transformers,
earth current of additional summation current transformer
6_27_LSA4827us.pdf
VA-N
E9
E11
Connection examples
networks
the V E voltage of the broken delta
A
B
C
A
1
B
da
dn
a
2
52
52
52
E9
VA-B
E11
VC-B
E12
E13
VN
E14
IA
F1
L
l
K
k
A
B
l
K
k
F6
4
C
L
F4
IC
F5
3
F2
IB
F3
6_29_LSA4792us.pdf
b
INs
F8
F7
SIPROTEC
5
(non directional element for phases)
6
detection.
A
B
C
A
7
B
da
52
52
VN
E13
IA
F1
IB
F3
IC
F5
L
l
K
k
A
B
C
L
l
K
k
INs
F8
SIPROTEC
E14
8
F2
F4
F6
F7
9
6_30_LSA4793us.pdf
dn
52
10
Connection examples
Connection for all types of power
systems
A directional earth-fault protection
is not possible, as the displacement
voltage cannot be calculated.
2
A
B
C
52
52
52
E9
A
a
B
A
b
a
B
b
E12
E11
F1
F3
3
L
l
K
k
VA-B
VC-B
IA
IB
IC
F8
F7
IN
F8
M
Fig. 6/31 Residual circuit with voltage functions
(non directional element for phase)
5
6
7
8
9
10
F4
F5
SIPROTEC
4
F2
6_31_LSA4859us.pdf
1
The illustration shows the connection
of three current transformers and two
voltage transformers in V-connection.
Connection types
Type of network
Function
Current connection
Voltage connection
networks
Overcurrent protection
phase / ground non-directional
–
networks
–
networks
non-directional
–
networks
Directional overcurrent protection,
phase
networks
phase
networks
ground-faults
required
Isolated networks
winding
cos ϕ measurement
winding
1
2
3
4
5
6
7
8
9
10
1
2
3
4
5
6
7
8
9
10
SIPROTEC Compact
Generator and Motor Protection 7SK81
Page
1
2
3
Description
7/3
Function overview
7/4
Applications
7/5
Application sheets
7/6
7/12
7/16
Connection diagrams
7/18
Connection examples
7/24
4
5
6
7
8
9
10
for Low-Power CT and VT Applications - Description
Description
The SIPROTEC 7SK81 provides 4 low-power current transformer inputs and optionally 3 low-power voltage transformer
inputs. With the same low-power current transformer (LPCT)
a wide range of primary rated line currents can be covered.
Objects with rated currents in the range of 40 A to 5000 A
can be protected when using low-power current transformers. The following low-power current transformer ratios are
suitable for the following primary current operating ranges:
1
2
LSP3.01-0026.eps
• 100 A/225 mV for a primary operating current range of
40 A … 600 A
• 50 A/22.5 mV for a primary operating current range of
200 A … 3000 A
• 400A/225mV for a primary operating current range of
200 A … 2500 A
• 100 A/22.5 mV for a primary operating current range of
400 A … 5000 A.
4
The SIPROTEC 7SK81 is a multi-functional motor protection
The relay provides numerous functions to respond flexibly to
the system requirements and to deploy the invested capital
economically. Examples for this are: exchangeable interfaces,
flexible protection functions and the integrated automation
level (CFC). Freely assignable LEDs and a six-line display
ensure a unique and clear display of the process states.
In combination with up to 9 function keys, the operating
personnel can react quickly and safely in any situation. This
guarantees a high operational reliability.
3
5
Fig. 7/1 SIPROTEC 7SK81 front view
6
Highlights
7
• Inputs for low power VTs and CTs according IEC 61869-6
(formerly IEC 60044-7 and IEC 60044-8)
LSP3.01-0008.eps
• Removable terminal blocks
• 6-line display
8
• USB front port
9
Ethernet rings
Fig. 7/2 SIPROTEC 7SK81 rear view
IEC 61850 GOOSE
Ethernet with SNTP.
10
for Low-Power CT and VT Applications - Function overview
1
2
IEC
ANSI
Instantaneous and definite time-overcurrent protection (phase/neutral)
I>, I >>, I >>>, IE>, IE>>, IE>>>; Ip, IEp
50, 50N; 51, 51N
Directional time-overcurrent protection, ground
67N
Directional overcurrent protection, ground (definite/inverse)
IEE>, IEE>>, IEEp
67Ns, 50Ns
Displacement voltage, zero-sequence voltage
V E, V 0>
59N
AKU
74TC
I<
37
ϑ>
49
Temperature monitoring
3
4
38
Load jam protection
51M
14
Restart inhibit
66/86
V<, V>
27/59
Forward-power, reverse-power protection
P<>, Q<>
32
Power factor
cos ϕ
55
f<, f>
81O/U
I 2>
46
Unbalance-voltage protection and/or phase-sequence monitoring
V2>, phase sequence
47
Breaker failure protection
5
48
Lockout
86
6
7
8
df / dt
81R
– IEC 60870-5-103
– PROFIBUS-DP
– DNP 3.0
– MODBUS RTU
9
50BF
• Ethernet interface for DIGSI 4, RTD box
Hardware
• Trip-circuit supervision
• Motor statistics.
• 4 current inputs
• 0/3 voltage inputs
• 0/5 RTD inputs
• 1 life contact
10
• Pluggable voltage terminals.
for Low-Power CT and VT Applications - Applications
The SIPROTEC 7SK81 unit is a numerical motor protection relay
for low power CT and VT inputs. It can perform control and
monitoring functions and therefore provide the user with a
cost-effective platform for power system management, that
The ergonomic design makes control easy from the relay front
panel. A large, easy-to-read display was a key design factor.
Control
Motor protection
The SIPROTEC 7SK81 device is specifically designed to protect
induction-type asynchronous motors.
SIPROTEC 7SK81 units can be used for line protection of high
and medium-voltage networks with grounded, low-resistance
grounded, isolated or a compensated neutral point.
The integrated logic characteristics (CFC) allow the user to add
own functions for automation of switchgear (e.g. interlocking)
or switching sequence. The user can also generate userdefined messages. This functionality can form the base to
create extremely flexible transfer schemes.
The SIPROTEC 7SK81 device provides all the functions for
backup protection for transformer differential protection. The
inrush suppression effectively prevents unwanted trips that
can be caused by inrush currents.
Backup protection
As a backup protection the SIPROTEC 7SK81 devices are
Busbar
CFC logic
Limits
86
AND
min/max-memory
Operation
Esc
7
8
9
4
1
5
2
6
3
Fn 0
.
P<>, Q<> cos˳
df/dt
Additional motor protection
I<
Fault recording
RS232/485/FO/
Ethernet
IEC 60870-5-103
IEC 61850
PROFIBUS-DP
DNP 3.0
MODBUS RTU
Enter
RTD-Box
5
66/86
14
37
Load Jam
48
32
55
81R
f<, f>
V>
V<
81U/O
59
27
8
Directional supplement (Ground)
51M
Jammed rotor protection
47
Motor statistics
38
6
V, f, P
I, V, P, Q,
cos ˳, f
Mean value
Lock out
4
7
Commands/Feedbacks
3
of high/medium-voltage applications. In general, no separate
measuring instruments (e.g., for current, voltage, frequency,
…) or additional control components are necessary.
2
Line protection
Programmable logic
52
1
9
Phase sequence
monitoring
Storage temperature
IN>, IN>>, IN-TOC
67N
50
ITO
C
51
ININ>, IN>>, TO
IN>>>
C
50N
51N
BF
I2>
46
49
InRush
BLK
fault protection
50BF
INs>,
INs>>
50N
67Ns
51N
IN>, IN>>, IN-TOC
IN>>>
66/86 Motor restart inhibit
48 Motor starting protection
67NsTOC
67NsTOC
VN>
59N
Visio-7SK81- fd-us.pdf
I>, I>>,
I>>>
10
for Low-Power CT and VT Applications - Application sheets
1
2
Directional overcurrent protection, ground (ANSI 67N)
Time-overcurrent protection (ANSI 50, 50N, 51, 51N)
transformers). Three definite-time overcurrent protection
Inverse-time overcurrent protection characteristics (IDMTL)
can also be selected and activated.
3
4
Directional ground protection is a separate function. It operates in parallel to the non-directional ground overcurrent
elements. Their pickup values and delay times can be set
separately. Definite-time and inverse-time characteristics
aroffered. The tripping characteristic can be rotated by
0 to ± 180 degrees.
zero-sequence voltage tends to be very low due to the
zero-sequence impedance it will be better to use the negative-sequence quantities.
to ANSI C37.112 and IEC 60255-3 /BS 142 standards. When
5
IEC 60255-3
Inverse

Short inverse
Long inverse
6
ANSI / IEEE



Moderately inverse


Very inverse


Extremely inverse


Table7/2 Available inverse-time characteristics
7
Inrush restraint
8
9
If second harmonic content is detected during the energization of a transformer, the pickup of stages I>, Ip, I>dir
10
Fig. 7/4 Directional characteristic of the directional time-overcurrent
protection, ground
(ANSI 59N/64, 67Ns, 67N)
Phase-balance current protection (ANSI 46)
(Negative-sequence protection)
active current component or residual resistive current is evaluated. For special network conditions, e.g. high-resistance
current or low-resistance grounded networks with ohmicinductive current, the tripping characteristics can be rotated
approximately ± 45 degrees (see Fig. 7/5).
phase-to-ground faults on the low side of a transformer (e.g.
Dy 5). This function provides backup protection for highresistance faults through the transformer.
• It has the following functions:
• Each element can be set to forward, reverse or nondirectional
2
another trip command can be initiated using the breaker failure protection which trips the circuit-breaker of an upstream
feeder. Breaker failure is detected if, after a trip command
is issued and the current keeps on flowing into the faulted
circuit. It is also possible to make use of the circuit-breaker
position contacts for indication as opposed to the current
flowing through the circuit-breaker.
3
4
SIPROTEC 7SK81 enables the user to easily add up to 20
under and overvoltage). All stages operate with protection
priority or speed.
Current
Voltage
Measured-value
processing
I measured
V measured
3I0, I1, I2
3V0, V1, V2
34
FRV˳
f
df/dt
dV/dt
Parameter
5
6
7
Time
t
Threshold
Function 1
Function 2
Function 20
Pickup
TRIP
command
Visio-flexProFunc-us.pdf
1
8
9
(ANSI 50Ns, 51Ns / 50N, 51N)
10
transformer is connected to a split-core low-power current
1
2
Protection functions/stages available are based on the available
measured analog quantities:
Function
ANSI
I>, IE>
50, 50N
V<, V>, VE>
27, 59, 59N
3I0>, I 1>, I2>, I2 / I1>, 3V0>, V1> <,V2 > <
50N, 46, 59N, 47
P> <, Q> <
32
cos ϕ
55
f><
81O, 81U
df / dt > <
81R
3
4
5
6
Lockout (ANSI 86)
stored in the event of supply voltage failure. Reclosure can only
occur after the lockout state is reset.
7
8
9
10
function with an integrated warning/alarm element for temperature and current can be used. The temperature is calculated
using a thermal homogeneous body model (per IEC 60255-8),
it considers the energy entering the equipment and the energy
losses. The calculated temperature is constantly adjusted according to the calculated losses. The function considers loading
history and fluctuations in load.
Protection of motors requires an additional time constant.
This is used to accurately determine the thermal heating of
the stator during the running and motor stopped conditions.
The ambient temperature or the temperature of the coolant
can be detected either through internal RTD inputs or via an
external RTD-box. The thermal replica of the overload function
is automatically adapted to the ambient conditions. If neither
internal RTD inputs nor an external RTD-box exist, it is assumed
that the ambient temperatures are constant.
times of the electromechanical relay (several hundred milliseconds) can lead to problems in terms of time coordina-tion/
for certain functions, such as time-overcurrent protection,
ground short-circuit and phase-balance current protection.
Motor protection
1
Restart inhibit (ANSI 66/86)
If a motor is subjected to many successive
starts, the rotor windings or rotor bars can
be heated up to a point where the electrical
connections between the rotor bars and the
end rings are damaged. As it is not possible
to physically measure the heat of the rotor
we need to determine the heat by measuring
the current the rotor is drawing through the
stator to excite the rotor. A thermal replica
of the rotor is established using a I2t curve.
The restart inhibit will block the user from
starting the motor if the relay determined
that the rotor reached a temperature that
will damage the rotor should a start be
attempted. The relay will thus only allow a
restart if the rotor has a sufficient thermal
reserve to start (see Fig.).
Emergency start-up
If the relay determines that a restart of the
motor is not allowed, the relay will issue
a block signal to the closing command,
effectively blocking any attempt to start the
motor. The emergency startup will defeat
this block signal if activated through a binary
input. The thermal replica can also be reset
to allow an emergency restart of the motor.
Temperature monitoring (ANSI 38)
2
3
T - TRIP
[s]
I STARTUP
Motor startup current
T max STARTUP cold
max. startup time of motor with
startup current from cold motor
T max STARTUP warm
max. warm motors startup times
I Pickup
Threshold of the function
5
6
T max STARTUP cold
T max STARTUP warm
4
Cold Motor
Warm Motor
Either 5 internal RTD inputs or up to 12
I
I Pickup
I STARTUP
RTD inputs through an external RTD box
can be applied for temperature detection.
Fig. 7/7 Starting time supervision characteristics
Example for the application with 5 internal
RTD inputs: Two RTDs can be applied to each
bearing (the cause of 50% of typical motor failures).
I A2
tAmax
tTRIP
The remaining RTD is used to measure the ambient temperaI
ture. Stator temperature is calculated by the current flowing
tTRIP
= Tripping time IA = Motor starting current
through the stator windings. Alternatively up to 12 RTDs
= Max. permissible starting time
tAmax
can be applied using an external RTD box connected either
I
= Actual current flowing
through RS485 on Port B or through Ethernet on Port A.
The RTDs can also be used to monitor the thermal status of
Because the flow of current is the cause of the heating of the
transformers or other pieces of primary equipment.
motor windings, this equation will accurately calculate the
starting supervision time. The accuracy will not be affected
Starting time supervision/Locked rotor protection
by reduced terminal voltage that could cause a prolonged
(ANSI 48/14)
start. The trip time is an inverse current dependant characte2
Starting time supervision protects the motor against unwant- ristic (I t).
ed prolonged starts that might occur in the event of excesBlock rotor can also be detected using a speed sensor consive load torque or excessive voltage drops within the motor,
nected to a binary input of the relay. If activated it will cause
or if the rotor is locked. Rotor temperature is calculated from
an instantaneous trip.
measured stator current. The tripping time is calculated
according to the following equation:
7
8
9
10
1
2
Load jam protection (ANSI 51M)
Load jam is activated when a sudden high load is applied to
the motor because of mechanical failure of a pump for example. The sudden rise in current is detected by this function
and can initiate an alarm or a trip. The overload function is
too slow and thus not suitable.
Unbalanced load protection (ANSI 46)
The unbalanced load protection detects a phase failure or
load unbalance due to system asymmetry, and protects the
rotor from impermissible overheating.
3
Motor statistics
4
Essential statistical information is saved by the relay during
a start. This includes the duration, current and voltage. The
relay will also provide data on the number of starts, total
operating time, total down time, etc. This data is saved as
statistics in the relay.
5
6
7
8
9
10
Further functions
Measured values
• Symmetrical components I1, I2, 3 I0; V1, V2, 3V0
selective)
• Frequency
voltage values
indication
Metered values
the 7SK81 can obtain and process metering pulses through
an indication input. The metered values can be displayed and
passed on to a control center as an accumulated value with
reset. A distinction is made between forward, reverse, active
and reactive energy.
maintenance intervals to be aligned to their actual degree
of wear. The benefit lies in reduced maintenance costs.
arc-chamber’s physical conditions into account when the
CB opens.
1
2
of operating cycles
at rated normal
current
of operating cycles
breaking current
• ΣI
Commissioning
x
• ΣI , with x = 1..3
• Σi2t.
3
4
5
6
7
8
Test operation
9
10
for Low-Power CT and VT Applications - Application examples
Radial systems
General hints:
1
2
1) Unbalanced load
faults
Infeed
A
52
Busbar
52
3
I>t
IN>t
I2>t
51
51N
46
1)
Busbar
C
*
4
5
52
I>t
IN>t
I2>t
51
51N
46
Load
Busbar
52
6
Load
7
I>t
IN>t
I2>t
51
51N
46
Load
Fig. 7/9 Protection concept with overcurrent-time protection
8
compensated systems
9
measurement of the
current transformer
Infeed
Busbar
I>>
I>t
50
51
IN>t dir.
10
1)
67Ns
Load
52
D
*
Small and medium-sized
motors < 1MW
52
I>, I>>,
I>>>
IN>t
>
IStart²t
I2>
50
51N
49
48
46
1
Visio-LSA4869a-en.pdf
Applicable, with effective and lowresistance infeed (IE ≥ IN, Motor), to
low-voltage motors and high-voltage
motors with low-resistance infeed
(IE ≥ IN, Motor).
2
M
Fig. 7/11 Protection concept for small motors
(IE ≤ IN, Motor)
measurement of the
current transformer
3
52
2) The sensitive directional
earth-fault detection
(ANSI 67Ns) is only
applicable with the
1)
infeed from an isolated
system or a system
earthed via Petersen coil.
I>>
>
50
49
IN>t
2)
51N
67Ns
IStart²t
461
PU
I<
48
46
37
Visio-LSA4870_-us.pdf
High-resistance infeed
4
M
5
Fig. 7/12 Protection concept for medium motors
Generators < 500 kW
Busbar
Medium-voltage
If a core balance current transformer for
sensitive ground-fault protection is available,
SIPROTEC 7SK80 should be used with
sensitive ground-current input.
6
G
I>t
IN>t
46-1
PU
51/51N
46
52
49
7
8
Fig. 7/13 Protection concept for smallest generators with solidly earthed neutral
Busbar
Medium-voltage
9
G1
Generator
2
*
RN =
I>t
IN>t
46-1
PU
51/51N
46
49
52
VNom
3 · (0.5 to 1) · INom
10
Fig. 7/14 Protection concept for smallest generators with low-resistance neutral earthing
Generators up to 1MW
Two voltage transformers in V
circuit are enough.
1
Busbar
52
2
f><
81
G
51
3
46-1 PU
49
46
P>
V>
32
I>t
59
IN>t
51N
4
Fig. 7/15 Protection concept for small generators
5
Infeed
I>>t0
6
50/50N
52
51/51N
t0 = 50 ms
Busbar
52
52
52
I>, I>>,
I>>>
I>t
I>, I>>,
I>>>
I>t
I>, I>>,
I>>>
I>t
50/50N
51/51N
50/50N
51/51N
50/50N
51/51N
8
Fig. 7/16 Busbar protection with reverse interlocking
9
10
7
In unstable power systems (e.g. solitary
systems, emergency power supply
in hospitals), it may be necessary to
isolate selected consumers from the
power system in order to protect 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.
1
2
Busbar
V<
f<
27
81U
I>, I>>,
I>>>
IN>>
I>, Ip
IN>,
INTOC
50
50N
51
51N
>
I2>
Final trip
49
46
86
3
52
4
5
Motor protection
For short-circuit protection, the stages
I>> and IE>> are available, for example.
Sudden load variations in running operation are acquired by the Iload> function. For isolated systems, the sensitive
earth-fault detection (IEE>>, V0>) can
be used. The stator is protected against
thermal overload by s, the rotor by
I2>, start-time supervision and restart
inhibit. A locked rotor is detected via
a binary input, and shut down as fast
as required. The restart inhibit can be
deactivated by an “emergency start”.
52
V<
V>
V0>
47
27
59
59N
I>, I>>,
I>>>
S>
46-1 PU
I<
ILoad>
50
49
46
37
51M
14
Blocked rotor
49
Motor starting protection
86
Motor restart inhibit
IN>
51N
Tachometer
6
Rotation
IN>>
or
67N
7
Visio-LSA220ba-us.pdf
The undervoltage function prevents a
start when the voltage is too low; the
overvoltage function prevents insulation damages.
Busbar
8
M
9
Fig. 7/18 Typical protection concept for an asynchronous high-voltage motor
10
for Low-Power CT and VT Applications - Selection and ordering data
Product description
1
Order No.
12345 6
7SK81
Short code
7 8 9 10 11 12 13 14 15 16 17 18 19
+
- 3
3-
2
3
Housing 1/6 19"; 4 x I, 3 BI, 5 BO (2 Changeover), 1 life ontact
1
2
3
4
Housing 1/6 19"; 4 x I, 3 BI, 5 BO (2 Changeover), 1 life contact, 5 RTD inputs
5
Housing 1/6 19"; 4 x I, 3 x V, 3 BI, 5 BO (2 Changeover), 1 life contact, 5 RTD inputs
6
Low Power Measuring Inputs
see next
page
3
Auxiliary voltage
4
DC 24 V / 48 V
1
DC 60 V / 110 V / 125 V / 220 V / 250 V, AC 115 V, AC 230 V
5
Construction
E
5
Region DE, IEC, language German (language changeable)
A
Region World, IEC/ANSI, language English (language changeable)
B
Port B (at bottom of device)
6
No port
IEC 60870-5-103 DIGSI 4/modem or RTD-box, electrical RS485
IEC 60870-5-103 DIGSI 4/modem or RTD-box, optical 820 nm, ST connector
7
8
0
1
2
3
9
L 0 A
9
L 0 B
9
L 0 D
9
L 0 E
9
L 0 G
9
L 0 H
9
L 0 P
9
L 0 R
9
L 0 S
9
No port
0
With Ethernet interface (DIGSI, RTD-box, not IEC 61850), RJ45 connector
6
10
3
for Low-Power CT and VT Applications - Selection and ordering data
ANSI No.
Product description
Order No.
Order No.Short code
12345 6
7 8 9 10 11 12 1314
1415
1516
16 17 18 19
7SK81
3-
-3
H D 0
Motor protection device
1
+
2)
2
Basic functionality
50/51
50N/51N
50N(s)/51N(s)1)
49
74TC
50BF
46
86
48
37
66/86
14
51M
Overcurrent protection, phase I>, I>>, I>>>, Ip
Overcurrent protection, ground IE>, IE>>, IE>>>, IEp
Sensitive ground fault protection IEE>, IEE>>, IEEp
Trip-circuit supervision, TCS
Circuit-breaker failure protection,CBFP
Lockout
Restart inhibit
Load jam protection
Motor statistics
Inrush restraint
3
4
H E 0
Basic functionality + Directional sensitive ground fault,
voltage and frequency protection
67N
67N(s)1)
59N
27/59
81 U/O
47
32/55/81R
5
3)
Directional overcurrent protection for ground-faults, IE>, IE>>, IEp
Senitive ground-fault detection for systems with resonant or isolated neutral, IEE>, IEE>>, IEEp
Overvoltage protection
Under-/overvoltage protection V<, V>
Under-/overfrequency protection f<, f>
Phase rotation
Flexible protection functions (current and voltage parameters)
Protection function for voltage, power, power factor, frequency change
6
7
8
9
10
1) Depending on the connected low-power current transformer the function will be either sensitive (IEE)
or non-sensitive (IE).
for Low-Power CT and VT Applications - Connection diagrams
1
IA
F2
IB
F3
IC
F4
IN, INS
BO1
C11
C9
C10
BO2
C14
C13
C12
BO3
E1
E2
E3
E4
E5
E6
BO4
3
BO5
4
C3
C4
C5
C6
C7
C8
5
BI1
BI2
BI3
Life Contact
E10
E8
E7
=
(~)
Power Supply
=
6
+
-
C1
C2
Port B
Port A
Ethernet interface
7
USB-DIGSI-Interface
8
9
10
B
A
250 V
2
F1
1
F1
IA
F2
IB
F3
IC
F4
IN, INS
BO1
C1 1
C9
C10
BO2
C1 4
C13
C12
BO3
E1
E2
E3
E4
E5
E6
D9
D10
D11
D12
D13
D14
BO4
BO5
BO6
BO7
C3
C4
C5
C6
C7
C8
BI1
D1
D2
D3
D4
D5
D6
D7
D8
BI4
BO8
BI2
BI3
3
4
E10
E8
E7
Life Contact
=
BI5
2
(~)
Power Supply
=
+
-
5
C1
C2
6
BI6
Port A
Ethernet interface
USB-DIGSI-Interface
B
A
7
250 V
BI7
Port B
8
9
10
1
F1
IA
VA-N
IB
VB-N
IC
VC-N
IN, INS
F2
F3
F4
C1 1
C9
C10
BO2
C1 4
C13
C12
BO3
E1
E2
E3
E4
E5
E6
BO4
3
BO5
4
C3
C4
C5
C6
C7
C8
5
BI1
BI2
BI3
E10
E8
E7
Life Contact
=
(~)
Power Supply
=
6
+
-
C1
C2
Port B
Port A
Ethernet interface
7
USB-DIGSI-Interface
8
9
10
B
A
250 V
2
BO1
1
F1
IA
VA-N
IB
VB-N
IC
VC-N
IN, INS
F2
F3
F4
BO1
C1 1
C9
C10
BO2
C1 4
C13
C12
BO3
E1
E2
E3
E4
E5
E6
D9
D10
D11
D12
D13
D14
BO4
BO5
BO6
BO7
C3
C4
C5
C6
C7
C8
BI1
D1
D2
D3
D4
D5
D6
D7
D8
BI4
BO8
BI2
2
3
4
BI3
=
BI5
5
E10
E8
E7
Life Contact
(~)
Power Supply
=
+
-
C1
C2
6
BI6
Port A
Ethernet interface
USB-DIGSI-Interface
B
A
7
250 V
BI7
Port B
8
9
10
1
IA
F2
IB
F3
IC
F4
IN, INS
BO1
C11
C9
C10
BO2
C14
C13
C12
BO3
E1
E2
E3
E4
E5
E6
BO4
3
BO5
4
C3
C4
C5
C6
C7
C8
5
BI1
E10
E8
E7
Life Contact
BI2
=
BI3
(~)
Power Supply
=
+
C1
C2
-
Port B
(+)
(-)
(+)
(-)
7
D1
D2
D5
D3
D4
(+)
(-)
D7
D8
D6
(+) D9
(-) D10
8
(+) D11
(-) D12
D13
9
RTD1
COMP12
Port A
Ethernet interface
A
USB-DIGSI-Interface
RTD2
RTD3
COMP34
RTD4
RTD5
COMP5
D14
*)
Visio-kl-7SK815-Fig 18-us.pdf
6
B
*) The shielding of the connecting cable is connected directly to the
shield cap.
10
2
F1
1
F2
F3
F4
IA
VA-N
IB
VB-N
IC
VC-N
IN, INS
BO1
C11
C9
C10
BO2
C14
C13
C12
2
BO3
E1
E2
E3
E4
E5
E6
3
E10
E8
E7
4
BO4
BO5
C3
C4
C5
C6
C7
C8
BI1
Life Contact
BI2
=
BI3
(~)
Power Supply
=
+
C1
C2
-
Port B
(+)
(-)
D1
D2
D5
D3
D4
(+)
(-)
D7
D8
D6
(+) D9
(-) D10
(+) D11
(-) D12
D13
D14
RTD1
COMP12
B
Port A
Ethernet interface
6
A
USB-DIGSI-Interface
RTD2
RTD3
COMP34
RTD4
Visio-kl-7SK816-Fig 19-us.pdf
(+)
(-)
5
RTD5
COMP5
*)
F1
7
8
9
*) The shielding of the connecting cable is connected directly to the
shield cap.
10
for Low-Power CT and VT Applications - Connection examples
52
52
52
F1
F2
2
F3
*
3
*
A
*
B
F4
IA
IB
IC
Visio-Figure-20-M-us.pdf
1
IN
SIPROTEC
C
M
4
Fig. 7/25 Connection to 3 low-power CTs, normal circuit layout,
appropriate for all networks
52
52
52
6
F1
F2
F3
7
*
A
*
B
*
C
F4
IA
IB
IC
IN
SIPROTEC
8
*
9
Fig. 7/26 Connection to 3 low-power CTs - additional low-power CT
for sensitive ground fault detection INS - only for isolated or
10
5
52
52
1
52
LPCT/LPVT
R2
*
1)
*
R1
F1
*
2
VA-N
IA
LPCT/LPVT
R2
*
1)
*
R1
F2
*
3
VB-N
IB
4
LPCT/LPVT
R2
*
*
R1
1)
F3
VC-N
IC
5
A
B
F4
C
IN
SIPROTEC
LPCT
*
6
*
7
8
Fig. 7/27 Connection for combined low-power current and voltage
transformers in phase L1, L2 and L3
9
10
52
52
52
LPVT
1)
*
R1
R2
Flush Mounting
Housing
RJ45 Y-Cable
*
1
F1 VA-N
IA
2
LPVT
R2
RJ45 Y-Cable
*
1)
*
R1
F2 VB-N
IB
LPVT
*
1)
R2
RJ45 Y-Cable
*
3
R1
F3 VC-N
IC
4
*
LPCT
A
*
LPCT
B
F4
LPCT
C
*
IN
SIPROTEC
5
*
LPCT
6
Fig. 7/28 Connection to low-power transformers for 3 phase currents, sensitive
ground current INS and 3 phase-to-ground voltages.
The LPCT and the LPVT are connected to SIPROTEC 7SK81 through a
Y-cable (refer to Fig. 7/29)
7
To 7SJ81/7SK81
RJ45 plug
8
7
6
5
4
3
2
1
8
1)
1)
9
1)
8
10
7
6
5
4
3
2
1
8
7
6
5
4
3
RJ45 socket
RJ45 socket
From low-power VT
(Voltage divider)
From low-power CT
1) The connections 5, 6, 7 and 8 are optional, but not mandatory.
Fig. 7/29 Y-cable for a connection of LPCT and LPVT with SIPROTEC 7SK81
2
1
Visio-Y-cable_us.pdf
1)
Voltage and Frequency Protection 7RW80
SIPROTEC Compact
Page
1
2
3
Description
8/3
Function overview
8/4
Applications
8/5
Application sheets
8/6
8/8
8/10
Connection diagrams
8/12
Connection examples
8/14
4
5
6
7
8
9
10
Description
Description
The SIPROTEC 7RW80 is a numerical, multi-function relay for
connection to voltage transformers. It can be used in distribution systems, on transformers and for electrical machines.
If the SIPROTEC Compact 7RW80 detects any deviation from
the permitted voltage, frequency or overexcitation values, it
will respond according to the values set. The relay can also
be applied for the purposes of system decoupling and for
load shedding if ever there is a risk of a system collapse as a
result of inadmissibly large frequency drops. An integrated
load restoration function allows the re-establishment of the
power system after recovery of the system frequency.
1
LSP3.01-0028.eps
2
The SIPROTEC 7RW80 features “flexible protection functions”.
the user. For example, a rate of change of frequency function
or a reverse power function can be created.
The relay provides circuit-breaker control, additional primary
switching devices (grounding switches, transfer switches
and isolating switches) can also be controlled from the relay.
Automation or PLC logic functionality is also implemented in
the relay.
The integrated programmable logic (CFC) allows the user
to add own functions, e.g. for the automation of switchgear (including: interlocking, transfer and load shedding
schemes). The user is also allowed to generate user-defined
messages. The communication module is independent from
the protection. It can easily be exchanged or upgraded to
future communication protocols.
3
4
5
Fig. 8/1 SIPROTEC 7RW80 front view
6
Highlights
7
• 6-line display
LSP3.01-0029.eps
• USB front port
Ethernet rings
9
IEC 61850 GOOSE
Ethernet with SNTP.
8
Fig.8/2 SIPROTEC 7RW80 rear view
10
Function overview
1
IEC
V<, V>
27/59
V E, V 0>
59N 1)
f<, f>
81O/U
Load restoration
2
81LR
Jump of voltage vector
Δϕ>
V/f
V2>, phase sequence
Synchrocheck
3
ANSI
24
47
25
df / dt
81R
dV / dt
27R/59R
AKU
74TC
Lockout
86
4
5
– IEC 60870-5-103
– PROFIBUS-DP
– DNP 3.0
– MODBUS RTU
• Control through keyboard, binary inputs, DIGSI 4 or
SCADA system
6
7
• Operational measured values V, f
• Ethernet interface for DIGSI 4
• Trip circuit supervision
Hardware
• 3 voltage transformers
• 1 life contact
• Pluggable terminal blocks.
8
9
10
1) Not available if function package “Q” or “E” (synchrocheck) is selected.
Applications
Line protection
The SIPROTEC 7RW80 unit is a numerical protection device
that can perform control and monitoring functions and
therefore provide the user with a cost-effective platform for
power system management, that ensures reliable supply of
electrical power to the customers. The ergonomic design
makes control easy from the relay front panel. A large, easyto-read display was a key design factor.
For the enhancement of the feeder protection the 7RW80
provides several stages for voltage and frequency protection.
1
Generator and transformer protection
Control
Programmable logic
Through implemented voltage, frequency and overexcitation
protection the SIPROTEC 7RW80 can be used for generators
and transformers in case of defective voltage or frequency
control, full load rejection or operation in islanding generation systems.
2
System decoupling and load shedding
3
For system decoupling and load shedding the SIPROTEC
7RW80 provides voltage, frequency, rate-of-frequencychange and rate-of-voltage-change protection.
Load restoration
4
For power system recovery, frequency protection and load
restoration are available in SIPROTEC 7RW80.
of high / medium-voltage applications. In general, no separate measuring instruments (e.g., for current, voltage, frequency, …) or additional control components are necessary.
5
6
7
8
Busbar
CFC logic
Commands/Feedbacks
86
Esc
AND
Enter
8
9
4
1
5
2
6
3
Fn 0
.
Mean value
V/f
min/max-memory
Synchrocheck
V/f
dV/dt
27R
59R
24
7
25
Limits
Lock out
Operation
RS232/485/FO/
Ethernet
IEC 60870-5-103
IEC 61850
PROFIBUS-DP
DNP 3.0
MODBUS RTU
9
df/dt
81R
f<, f>
V>
V<
81U/O
59
27
Fault recording
˂˳!
LR
Vector jump
Load Restoration
47
Phase sequence
59N VN>
1)
Visio-SIP-0001-us.pdf
52
1) Not available if function package “Q” (synchrocheck) is selected.
10
Application sheets
1
2
3
conditions of electrical machines are best evaluated with the
positive-sequence quantities. The protection function is active over a wide frequency range of 25 to 70 Hz. The function can operate either with phase-to-phase, phase-toground or positive phase-sequence voltage. Three-phase
and single-phase connections are possible. In addition a user
definable curve with up to 20 value pairs is available.
4
5
In addition, a user definable curve with up to 20 value pairs
is available.
6
7
8
9
Frequency protection can be used for overfrequency and underfrequency protection. Electric machines and parts of the
system are protected from unwanted frequency 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 of 25 to 70 Hz. There are four elements
(individually set as overfrequency, underfrequency or OFF)
and each element can be delayed separately. Blocking of the
frequency protection can be performed by activating
a binary input or by using an undervoltage element.
Overexcitation protection (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 25 to 70 Hz.
Jump of voltage vector
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 will be issued if the set threshold is exceeded.
SIPROTEC 7RW80 enables the user to easily add up to 20
command, a block function, etc.
Load restoration
The load restoration function provides an automatic reconnection of power system parts when the system frequency
has recovered after load shedding. Four load restoration
stages are available. They can be switched on and off separately. If the frequency conditions allow the assumption of
sufficient generation resources, the load restoration function
will consecutively reconnect small load parts at specified
time intervals.
10
dV/dt
SIP-0002.en.ai
The mode of operation for voltage quantities can be threephase or single-phase. Almost all quantities can be operated
with ascending or descending pickup stages (e.g. under and
overvoltage). All stages operate with protection priority or
speed.
Application sheets
Function
ANSI
V<, V>, VE>
27, 59, 59N
3V0>, V1> <, V2> <
59N, 47
f><
81O, 81U
df / dt > <
81R
dV / dt
27R/59R
Further functions
Measured values
The r.m.s. values are calculated from the acquired voltages
along with the frequency. The following functions are
available for measured value processing:
• Voltages VL1, VL2, VL3, VL1L2, VL2L3, VL3L1
• Symmetrical components V1, V2, V0
• Mean as well as minimum and maximum voltage values
indication
two separate networks are synchronized. Voltage-, frequency- and phase-angle-differences are checked to determine
whether synchronous conditions exist.
Lockout (ANSI 86)
Customized functions
Additional functions can be implemented using CFC or
flexible protection functions.
2
• Frequency
• Rate-of-voltage-change protection (ANSI 27R/59R).
1
3
4
Commissioning
Test operation
5
6
7
8
9
10
2
3
the overall system.
V>
V>>
V/f=f(t)
52
59
24
7RW80
The overcurrent protection functions
short-circuit.
f<>
V<
V<<
81
27
V>
V>>
59
7RW80
drop.
52
Network coupling
52
˂˳!
f<>
V<
V<<
Vector jump
81
27
52
V>
V>>
LR
59
Load Restoration
f<>
V<
V<<
V>
V>>
81
27
59
7RW80
4
52
M
7RW80
Network decoupling
Load shedding
Fig. 8/5 Application example 7RW80
5
6
7
8
9
From the measured frequency, the
frequency difference is determined
over a time interval. It corresponds to
the momentary frequency change.
It is thus possible to quickly detect any
major load drops in the power system,
to disconnect certain consumers
from the system, and to restore the
system to stability. Unlike frequency
protection, rate-of-frequency-changeprotection already reacts before the
pickup threshold of the frequency
protection is reached.
The pickup value depends on the application, and follows the conditions
of the power system. The rate-offrequency-change protection function
can also be used for the purposes of
system decoupling.
10
50
Hz
f
fm
t
49
fa
fb
SIP-0016.de.ai
Load shedding with rate-offrequency-change protection
fc
48
0
1
Fig. 8/6 Load shedding
2
3
4
t
5
SIP-0015a-en.pdf
1
Synchrocheck
1
Busbar
V2
52
Closing Signal
2
1
Transformer
V1
Local/remote
control
2
1)
SYN
25
2)
Infeed
81
G
1)
2)
AR
SIP C-0022-en.pdf
Where two system sections are interconnected, the synchrocheck determines whether the connection is permissible without danger to the stability
of the power system. In the example,
load is supplied from a generator
to a busbar through a transformer.
The vector group of the transformer
can be considered by means of a
programmable angle adjustment, so
that no external adjustment elements
are necessary. Synchrocheck can be
used for auto-reclosure, as well as for
control functions (local or remote).
Synchrocheck
Automatic reclosing
Fig. 8/7 Measurement of busbar and feeder voltage
for synchronization
3
4
5
6
7
8
9
10
Product description
Order No.
Short code
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19
1
7RW80
0-
-
+
Voltage and frequency relay
Housing, binary inputs and outputs
2
Housing 1/6 19", 3x V, 3 BI, 5 BO 1) , 1 life contact
1
Housing 1/6 19", 3x V, 7 BI, 8 BO 1) , 1 life contact
2
DC 24 V/48 V
1
DC 60 V/110 V/125 V/220 V/250 V, AC 115 V, AC 230 V
5
see
next
page
Unit version
3
Surface mounting housing, screw-type terminal
B
E
Region DE, IEC, language German 2), standard front
4
Region World, IEC/ANSI, language English 2), standard front
Region US, ANSI, language US-English 2), US front
Region FR, IEC/ANSI, language French 2), standard front
Region World, IEC/ANSI, language Spanish 2), standard front
Region World, IEC/ANSI, language Italian 2), standard front
5
Region RUS, IEC/ANSI, language Russian 2), standard front
Region CHN, IEC/ANSI, language Chinese 3), chinese front
A
B
C
D
E
F
G
K
6
No port
0
1
IEC 60870-5-103 or DIGSI 4/modem, optical 820 nm, ST connector
7
3
9
L 0 A
9
L 0 B
8
2
L 0 D
9
9
9
L 0 E
L 0 G
9
9
L 0 H
L 0 R
9
L 0 S
Port A (at bottom of device, front)
9
No port
0
With Ethernet interface (DIGSI, not IEC 61850), RJ45 connector
6
10
1) 2 changeover/Form C.
2) Language selectable
3) Language not changeable
1
ANSI No.
Product description
Order No.
Bestell-Nr.
Short code
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19
7RW80
0-
-
Voltage and frequency protection
27/59
64/59N
81U/O
47
74TC
86
27R/59R/81R
A
Under/Overvoltage
Under/Overfrequency
Phase rotation
Lockout
Flexible protection functions (voltage parameters): Rate-of-frequency change, rate-of-voltage change
47
74TC
86
27R/59R/81R
27R/59R/81R
47
74TC
86
27R/59R/81R
25
47
74TC
86
27R/59R/81R
5
C
6
7
D
Under/Overvoltage
Under/Overfrequency
Overexcitation
Vector jump
Phase rotation
Lockout
Voltage, frequency, overexcitation protection and vector jump, load restoration and synchrocheck
27/59
81U/O
24
4
Under/Overvoltage
Under/Overfrequency
Synchrocheck
Phase rotation
Lockout
Voltage, frequency, overexcitation protection and vector jump
27/59
64/59N
81U/O
24
3
Under/Overvoltage
Under/Overfrequency
Load restoration
Phase rotation
Lockout
Voltage, frequency protection and synchrocheck
27/59
81U/O
25
47
74TC
86
2
B
Voltage, frequency protection and load restoration
27/59
64/59N
81U/O
1
D D 0 +0
Under/Overvoltage
Under/Overfrequency
Overexcitation
Vector jump
Load restoration
Synchrocheck
Phase rotation
Lockout
8
9
E
10
Connection diagrams
1
2
C11
C9
C10
BO2
C14
C13
C12
BI1
BO3
BI2
BO4
BI3
BO5
E1
E2
E3
E4
E5
E6
VC, VN, Vsyn, VX
C3
C4
C5
C6
C7
C8
3
BO1
VA, VAB, Vph-n
VB, VBC
E10
E8
E7
Life Contact
4
=
(~)
Power Supply
=
5
+
-
C1
C2
Port B
Port A
Ethernet interface
6
8_8_SIP-0011us.pdf
USB-DIGSI-Interface
7
Fig. 8/8 Voltage and frequency protection SIPROTEC 7RW801
8
9
10
B
A
250 V
E9 Q2
E11
E12
E13
E14
Connection diagrams
1
E9 Q2
E11
E12
E13
E14
VA, VAB, Vph-n
VB, VBC
VC, VN, Vsyn, VX
BO1
C1 1
C9
C10
BO2
C1 4
C13
C12
E1
E2
E3
E4
E5
E6
D9
D10
D11
D12
D13
D14
C3
C4
C5
C6
C7
C8
BI1
BO3
BI2
BO4
BI3
BO5
D1
D2
D3
D4
D5
D6
D7
D8
BI4
BO6
BO7
BI5
BO8
BI6
2
3
4
BI7
E10
E8
E7
Life Contact
=
(~)
=
+
-
C1
C2
Port B
Port A
Ethernet interface
A
USB-DIGSI-Interface
8_9_SIP-0012us.pdf
6
B
7
250 V
Power Supply
5
8
Fig. 8/9 Voltage and frequency protection SIPROTEC 7RW802
9
10
Connection examples
Standard connection
A
B
C
1
52
Housing
52
2
A
E9
VA
E11
VB
B
E12
a
A
3
B
b
VC
E13
E14
SIPROTEC
C
8_10_SIP-0006us.pdf
52
Fig. 8/10 Example for connection type "VAN, VBN, VCN" load-side voltage connection
4
A
B
C
A
B
da
5
dn
a
52
52
b
6
A
7
B
E9
VA-B
E11
VC-B
E12
E14
VN
E13
C
8_11_SIP-0007us.pdf
52
SIPROTEC
Fig. 8/11 Voltage transformer connections to two voltage transformers
(phase-to-phase voltages) and broken data winding (da-dn)
A
B
C
Connection Vx
52
52
Housing
52
E9
9
A
B
VA-B
E12
E11
a
b
E13
E14
VC-B
Vx
SIPROTEC
10
A
B
a
A
B
b
C
Fig. 8/12 Example for connection type "VAB, VBC, Vx"
5_12_SIP-0008us.pdf
8
Connection examples
Connection for synchrocheck
A
B
C
52
52
B
a
b
VA-B
E9
A
B
1
Housing
VC-B
E11
a
b
VSyn
E14
E13
SIPROTEC
A
B
2
E12
C
8_13_SIP-0010us.pdf
52
A
3
Fig. 8/13 Example for connection type “VAB, VBC, VSYN”
4
A
B
C
A
52
52
B
a
A
E9
b
E12
E11
E13
E14
B
C
VPh-N
B
a
A
5
Housing
b
V-Transformer2
VSyn
SIPROTEC
6
8_14_SIP-0009us.pdf
52
7
Fig. 8/14 Example for connection type "Vph-n, Vsyn".
The connection can be established at any one of the three phases.
The phase must be the same for Vph-n and Vsyn.
8
9
10
1
2
3
4
5
6
7
8
9
10
Feeder Protection 7SC80
SIPROTEC Compact
Page
1
2
3
4
5
Description
9/3
Function overview
9/4
Applications
9/5
9/6
Transformers
9/7
Function description
9/8
9/14
9/20
Connection diagrams
9/22
Connection examples
9/26
Connection types
9/30
SNTP Server/Master
9/31
6
7
8
9
10
Description
Description
The SIPROTEC 7SC80 feeder protection can be used for
protection and automation of medium-voltage distribution
feeders with grounded, low-resistance grounded, isolated, or
compensated neutral.
1
The SIPROTEC 7SC80 features “flexible protection functions”.
20 additional protection functions can be created by the
user. For example, a rate of change of frequency function
or a reverse power function can be created. The relay
provides circuit-breaker control. Additional primary switching
devices (grounding switches, transfer switches and isolating
switches) can also be controlled from the relay. Automation
or PLC logic functionality is also implemented in the device.
2
3
SIP-COM-01.tif
The integrated programmable logic (CFC) allows the user to
add own functions, e.g. for the automation of switchgear
(including: interlocking, transfer and load shedding
schemes). The user is also allowed to generate user-defined
messages.
4
The upgrade of device and communication firmware is also
possible via Ethernet.
Highlights
5
Fig. 9/1 SIPROTEC 7SC80 front view with HMI
6
7
8
SIP-COM-02.tif
• Support of feeder automation applications, e.g. fault isolation
and service restauration
• Designed for harsh environment
• Extended temperature range –50 °C up to 85 °C
• Open for all different communication technologies, e.g.
radio, which are used for feeder automation
• Integrated GPS module is available for time synchronisation
• Full remote access supported for firmware and parameter
updates and upgrades
• A web based HMI provides complete remote control of the
device
• 6-line display
• Integrated switch for low-cost and redundant optical rings.
Devices can be connected directly with each other at
electrical modules
• Parallel running communication protocols
• Redundancy protocols RSTP, PRP and HSR for highest
availability
• Current Jump detector
• Extended CFC capabilities
• 24 km Single mode interface
• RTU version without protection features
• Pluggable terminals
• Secondary current transformers values (1 A / 5 A9 settable
using DIGSI
• Buffer battery exchangeable from the side
• USB front port
IEC 61850 GOOSE
• Stainless steel housing
9
Fig. 9/2 SIPROTEC 7SC80 side view with detached HMI
Ethernet with SNTP
• Inputs for Low power CTs and VTs according IEC 61869-6
(formerly IEC 60044-7 and IEC 60044-8).
10
Function overview
1
2
IEC
ANSI No.
Definite and inverse time-overcurrent protection (phase/ground)
I>, Ip, INp
50, 50N; 51, 51N
Directional time-overcurrent protection phase
I>, I>>, I>>>, Ip
67
Directional time-overcurrent protection ground
IE>, IE>>, IE>>>, IEp
67N
Directional sensitive ground fault protection
IEE>, IEE>>, IEEp
67Ns, 50Ns
V E, V 0>
59N
High-impedance restricted ground-fault protection
87N
Inrush restraint
3
4
5
Trip-ciruit supervision
TCS
74TC
I<, P>
37
Overload protection
ϑ>
49
V<, V>
27/59
f<, f>
81O/U
CBFP
50BF
I 2>
46
51V
LA, LB, LC
47
Synchrocheck
Sync
25
Automatic reclosing
AR
79
Fault locator
FL
FL
Lockout
6
86
P<>, Q<>
32
Power factor
cos ϕ
55
df / dt
81R
dV/dt
27R, 59R
7
8
9
• Commands for the ctrl. of CB, disconnect
switches (isolators/isolating switches)
• Ethernet electrical and optical
(miltimode or singlemode)
• IEC 61850 Edition 1 and 2
• User-defined PLC logic with CFC
(e.g. interlocking).
• PROFINET
• Ethernet redundancy protocols RSTP, PRP and HSR
Hardware
10
• Trip circuit supervision.
• DNP3 TCP
• IEC 60870-5-104
• 12 binary inputs
• 8 binary outputs
• 1 life contact
• Pluggable current and voltage terminal blocks
• Connection option for low-power current and
voltage transformers.
Applications
The feeder protection SIPROTEC 7SC80 is a numerical
protection device that can perform control and monitoring
functions and therefore provides the user with a costeffective platform for power system management, that
Device operation was designed according to ergonomic
aspects. Top priority was given to good display readability
and large function keys. The 32 LEDs allow displaying
numerous states and alarms.
Line protection
are stored in the relay to provide the user or operator with
all the key data required to operate modern substations.
The SIPROTEC 7SC80 units can also be used for line protection of medium-voltage distribution feeders with grounded,
low-resistance grounded, isolated, or compensated neutral.
Control
1
2
The integrated control function permits control of disconnect devices, grounding switches or circuit-breakers through
systems control (e.g. SICAM).
Programmable logic
add own functions for automation of switchgear (e.g. interlocking), switching sequence or of the distribution system.
The user can also generate user-defined messages.
The device provides all the functions for backup protection
for transformer differential protection. The inrush suppression effectively prevents unwanted trips that can be caused
by inrush currents. The high-impedance restricted groundfault protection detects short-circuits and insulation faults
on the transformer.
3
4
Backup protection
As a backup protection the SIPROTEC 7SJ80 devices are
Extensive measured values, metered values and limit
values provide improved system management as well as
commissioning.
of high / medium-voltage applications. In general, no
separate measuring instruments (e.g., for current, voltage,
frequency, …) or additional control components are
necessary.
5
6
Busbar
CFC logic
Commands/Feedbacks
86
Trip Circuit Supervision
AND
Lock out
Limits
I, V, P, Q,
cos ¶, f
Mean value
min/max-memory
Communication
module
Operation
Ethernet
IEC 61850
DNP3 TCP
PROFINET IO
IEC60870-5-104
Fault recording
Fault locator
Triple/Single pole
operation
V>
27
59
25
I-TOC
IN>, IN>>,
IN>>>
IN-TOC
50
51
50N
50N
51N
87N
IN>, IN>>,
IN>>>
IN-TOC
REF
51N
Synchrocheck
8
V, f, P
27R
59R
32
55
f<, f>
V>
V<
81U/O
59
27
81R
9
21FL
47
I>, I>>,
I>>>
7
P<>, Q<> cos ˳ df/dt
dV/dt
Time
Synchronization
- GPS
- SNTP
V<
I2>
46
BF
ϑ>
49
InRush
BLK
79
50BF
AR
67
I<
51c
37
Phase sequence
I>, I>>, ITOC
IN>, IN>>, INTOC
67N
51V
9_3_Visio-FuncDia-us__.pdf
mm 52
74TC
Vx
fault protection
67Ns
59N
INs>,
INs>>,
67Ns-TOC
VN>
10
2
3
4
5
6
The SIPROTEC 7SC80 has a complete other form factor than
all other SIPROTEC Compact devices. All interfaces are at the
left and right hand side of the relay. A small print onto the
enclosure next to the clamps describes each port in detail.
All clamps are pluggable and therefore a pre-wiring and
easy replacement in case of maintenance is possible. A short
circuit is integrated in the pluggable CT clamp to avoid any
risk of unclosed secondary CT circuits. The first eight binary
inputs and the second four binary inputs have a common
ground. The threshold is fixed for 24 V and higher. The
secondary values of the CTs 1 A or 5 A can be set via DIGSI.
SIP-COM-03.tif
1
SIP-COM-04.tif
Housing with many advantages
Operation panel/HMI
The relay features both a clip-on and a web-based operation
panel/HMI (web monitor) with 32 LEDs and 9 programmable
keys that can be used to configure shortcuts for menu
operations or other applications (see Fig. 9/6).
Fig. 9/4
Process termial
Fig. 9/6
WebMonitor
Fig. 9/5
Current terminal
The web monitor can be started just by entering the device
IP address in an internet browser. All device monitoring and
control functions are thus available in real-time through a
communication link. The access rights can be restricted. If
security requirements are more stringent, this function can
also be disabled completely.
The second web monitor view provides a graphic display
which represents control displays and also enables control
operations. Additionally, the web monitor gives access
to operational indications, protection indications, fault
records, primary and secondary values.
7
8
The operation panel/HMI is not mandatory for the correct
functioning of the SIPROTEC 7SC80. It can be attached or
detached during operation without any adverse effects. It is
installed either directly on the SIPROTEC 7SC80 base device
or connected detached using a 3 m cable.
SIPROTEC 7SC80 is suited for panel flush mounting or panel
surface mounting.
Current terminals – single cables
9
Cable cross-sections
AWG 14-12 (2.6 mm2 to 3.3 mm2)
When using lugs
AWG 14-10 (2.6 mm2 to 6.6 mm2)
Permissible tightening torque
2.7 Nm
Stripping length
(for solid conductor)
10 mm to 11 mm (0.39 in to 0.43 in)
Only solid copper wires may be used.
Process terminal connections
10
Cable cross-sections
AWG 18-12 (1.0 mm2 to 2.5 mm2)
Permissible voltages
300 V
Permissible currents
5A
Only solid copper wires may be used.
Permissible tightening torque
0.4 - 0.5 Nm
Stripping length
7 mm (0.28 in)
Table 9/2 Wiring specifications for process connection
SIP-COM-05.tif
You can print or save this data.
The SIPROTEC 7SC80 variants are always equipped with at
least one single voltage input Vx. This input can be used e.g.
to detect line voltage of a single phase.
An optional internal GPS module can be ordered to provide
high accuracy time synchronization to the device. The GPS
coordinates of the device can e.g. be provided to a control
center.
The SIPROTEC 7SC80 devices are always equipped with
either an electrical or an optical Ethernet module. IEC 61850
is always available on the module and optionally together
with one of the protocolls IEC 60870-5-104, PROFINET IO or
DNP3 TCP.
The optical module can be equipped with single mode ports
to bridge distances up to 24 km, the well known integrated
ethernet switch functionality is of course included.
Transformers
Low-power transformer terminals
Low-power voltage transformers
The SIPROTEC 7SC80 is available in two hardware configurations, featuring 3 inputs for connecting low-power current
transformers (if the ground current has to be measured
separately, the input Vx can be used) and optionally 3 inputs
for voltage transformers. Here, the low-power voltage
transformers are connected to the standard voltage transformer inputs. The required measuring range is activated
via parameter set. A secondary voltage corresponding to
the primary value is required; differential sensors are not
supported.
Resistive voltage dividers are provided as low-power
voltage transformers. You can generally connect all
sensors that support the following SIPROTEC 7SC80
specifications:
Low-power current transformers
You can generally connect all sensors to the low-power
current transformer inputs that support the following
SIPROTEC 7SC80 specifications:
Measuring range
20mV - 50V AC
(measuring accuracy +/- 1mV at 25°C)
Input impedance
40 kOhms
Rated voltage
200mV - 20V at rated current
Thermal rating
200V for 10s
Cable
2-pole shielded, open cable end
1
Measuring range
100mV - 250V AC
(measuring accuracy +/- 1mV at 25°C)
Input impedance
1.2 MOhms (mismatches can be corrected
in the 7SC80 parameters if necessary)
Rated voltage
200mV - 40V
Thermal rating
230V continuous
Cable
2-pole shielded, open cable end
3
This enables various rated operating voltage ranges
depending on the sensors used.
4
5
IC_SG_Spannungssensor_W3.sRGB.png
This enables various rated operating current ranges depending on the sensors used. To prevent early saturation, the
overcurrents to be expected must also be observed in the
low-power transformers.
Voltage transformer
IC_SG_Stromsensor_W3_sRGB.png
Fig. 9/8
Fig. 9/7
2
6
7
8
9
Current transformer
The following low-power transformers can be ordered directly via MLFB:
Typ
MLFB
Ratio
Description
Phase current sensor
6MD2320-0GA00-1AA0
300A/225mV
split core transformer for cable systems; internal diameter 52
mm; accuracy 1 %, 5P10; impedance > 20 kohms
Summation current
6MD2320-0AF00-1AA0
60A/225mV
sensor split core transformer for cable systems; internal diameter
110 mm; impedance > 20 kohms
Voltage senso 10kV
6MD2320-0AA04-1AA0
10kV/√3 -> 3.25/√3
for T-connector with C-taper; accuracy 99 %, rated burden 200
kohms
Voltage senso 20kV
6MD2320-0AA07-1AA0
20kV/√3 -> 3.25/√3
for T-connector with C-taper; accuracy 99 %, rated burden 200
kohms
Table 9/3 Available low-power transofrmers e.g. Zelisko
10
1
2
3
4
5
6
7
Battery monitor
The DC 24/48 V auxiliary voltage version allows monitoring an external 24 V or 48 V battery. The DC voltage is
measured directly and provided as measured value. The
battery is tested periodically. For this purpose, the external
battery loader is deactivated temporarily, and after a short
waiting time, an external load impedance is connected to
the battery. The battery voltage before and after the test is
measured. If the voltage difference is too great, a message
can be generated. A number of other battery-related
messages are available. The battery status is also indicated
by a special battery LED.
Characteristics
acc. to
IEC 60255-3
ANSI / IEEE
Normal invers


Short inverse
Long inveres


Moderately inverse


Very inverse


Extremely inverse


ground elements. The current threshold and the delay
time can be set in a wide range. Inverse-time overcurrent
protection characteristics (IDMTL) can also be selected and
activated.
Moreover there are further recloser inverse-time characteristic curves available.
The tripping characteristic can be rotated by ± 180 degrees.
By making use of the voltage memory, the directionality
can be determined reliably even for close-in (local) faults.
If the primary switching device closes onto a fault and the
voltage is too low to determine direction, the direction is
determined using voltage from the memorized voltage. If no
voltages are stored in the memory, tripping will be according to the set characteristic.
using the reset characteristic (disk emulation), the 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 (disk
emulation).
Inrush restraint
8
comparison protection, the directional coordinated timeovercurrent protection is used for complete selective backup
protection.
The relay features second harmonic restraint. If second
harmonic content is detected during the energization of
a transformer, the pickup of stages (I>, Ip, I> dir and Ip dir is
blocked.
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.
zero-sequence voltage tends to be very low due to the zerosequence impedance it will be better to use the negativesequence quantities.
Dynamic setting change
9
The pickup thresholds and the trip times of the directional
and non-directional time-overcurrent protection functions
can be changed via binary inputs or by setable time control.
Static parameter switchover
Numerous protection-relevant parameters can be switched
over statically, e.g. via binary contacts, protocol or internal
logic. 8 parameter groups are available.
10
protection is suitable if the distances between the protection zones are not significant and pilot wires are available
for signal transmission. In addition to the directional
Fig. 9/9 Directional characteristics of the directional
time-overcurrent protection
(ANSI 59N/64, 67Ns, 67N)
Phase-balance current protection (ANSI 46)
(Negative-sequence protection)
active current component or residual resistive current is
evaluated.
phase-to-ground faults on the low side of a transformer. This
function provides backup protection for high-resistance faults
through the transformer.
For special network conditions, e.g. high-resistance
current or lowresistance grounded networks with ohmicinductive current, the tripping characteristics can be rotated
approximately ± 45 degrees (see Fig.9/10).
non-directional
2
(ANSI 50Ns, 51Ns / 50N, 51N)
• TRIP via the displacement voltage V E
1
trip command can be initiated using the breaker failure
protection which trips the circuit-breaker of an upstream
feeder. Breaker failure is detected if, after a trip command is
issued the current keeps on flowing into the faulted circuit.
It is also possible to make use of the circuit-breaker position
contacts for indication as opposed to the current flowing
through the circuit-breaker.
High-impedance restricted ground-fault protection (ANSI
87N)
3
4
5
6
The high-impedance measurement principle is a simple
and sensitive method to detect ground faults, especially on
transformers. It can also be used on motors, generators and
reactors when they are operated on a grounded network.
7
When applying the high-impedance measurement principle,
all current transformers in the protected area are connected
in parallel and operated through one common resistor of
relatively high R. The voltage is measured across this resistor
(see Fig. 9/11).
8
9
LSA4115-de.ai
Fig. 9/11 High-impedance restricted ground-fault protection
10
The voltage is measured by detecting the current through
the (external) resistor R at the sensitive current measurement input I EE. The varistor V serves to limit the voltage in
the event of an internal fault.
1
It limits the high instantaneous voltage spikes that can
occur at current transformer saturation. At the same time,
this results to smooth the voltage without any noteworthy
reduction of the average value.
2
If no faults have occurred and in the event of external or
through 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 flowing through the resistor R.
3
The same type of current transformers must be used and
must at least offer a separate core for the high-impedance
restricted ground-fault protection. They must have the
same transformation ratio and approximately an identical
knee-point voltage. They should also have only minimal
measuring errors.
4
Auto-reclosure (ANSI 79)
5
• 1/3-pole ARC for all types of faults
6
7
8
9
10
Current
Voltage
Measured-value
processing
I measured
V measured
3I0, I1, I2
3V0, V1, V2
34
FRV˳
f
df/dt
Parameter
Time
t
Pickup
AUSKommando
Threshold
Function 1
Function 2
Function 20
Protection functions/stages available are based on the available measured analog quantities:
Function
ANSI
I>, IE>
50, 50N
V<, V>, VE>
27, 59, 59N
3I0>, I1>, I2>, I2 / I1>, 3V0>, V1> <, V2 > <
50N, 46, 59N, 47
P> <, Q> <
32
cos ϕ
55
f><
81O, 81U
df / dt > <
81R
dI / dt > <
current jump function
• Multiple ARC, one rapid auto-reclosure (RAR) and up to nine
delayed auto-reclosures (DAR)
selected (e.g. I2>, I>>, Ip, Idir >)
• The ARC function can be blocked by activating a binary input
• The ARC can be initiated from external or by the PLC logic (CFC)
• Simplified differential protection via IEC 61850 GOOSE
communication.
• The directional and non-directional elements can either be
blocked or operated non-delayed depending on the autoreclosure cycle
• Rate-of-voltage-change protection (ANSI 27R/59R)
two separate networks are synchronized. Voltage-,
frequency- and phase-angle-differences are checked to
determine whether synchronous conditions exist.
SIPROTEC 7SC80 devices enables the user to easily add up
to 20 additional protection functions. Parameter definitions
under and over voltage). All stages operate with protection
priority.
Lockout (ANSI 86)
key is used to reset the lockout state. The lockout state is
also stored in the event of supply voltage failure. Reclosure
can only occur after the lockout state is reset.
1-pole operation
1-pole operation is optionally possible; switching objects
can be opened and closed for each phase. Furthermore,
1-pole tripping on a fault and automatic reclosing is possible
for each phase.
times of the electromechanical relay (several hundred milliseconds) can lead to problems in terms of time coordination/
for certain functions such as overcurrent protection, ground
The two-element overvoltage protection (possible per
phase)detects unwanted network and machine overvoltage
conditions. The function can operate either with phaseto-phase, phase-to-ground, positive phase-sequence or
negative phase-sequence voltage.
1
2
60 Hz)). There are four elements (individually set as overfrequency, underfrequency or OFF) and each element can be
delayed separately. Blocking of the frequency protection
3
4
Fault locator (ANSI FL)
5
Additional functions, which are not time critical, can be
implemented using the CFC measured values. Typical
functions include reverse power, voltage controlled overcurrent, phase angle detection, and zero-sequence voltage
detection.
6
7
continues to work, however, with decreased accuracy.
The function can operate either with phase-to-phase,
phase-to-ground or positive phase-sequence voltage, and
can be monitored with a current criterion. Three-phase and
single-phase connections are possible.
8
9
10
Further functions
1
Measured values
and reactive power. The following functions are available
for measured value processing:
2
• Currents IL1, I L2, IL3, I N, I EE
• Voltages U L1, U L2, U L3, U12, U23, U31
• Symmetrical components I1, I2, 3I0; U1, U2, 3U 0
selective)
3
• Power factor (cos ϕ), (total and phase selective)
• Frequency
voltage values
4
5
There is no exact mathematical method to calculate the
wear or the remaining service life of a circuit-breaker that
takes arc-chamber’s physical conditions into account when
the CB opens.
• ΣI
• ΣI x , with x = 1..3
• Σi2t.
• DC voltage measurement of an external battery
indication
Metered values
7
• Measurement of the internal device temperature
6
below or exceeds the limit value during determination of
the remaining service life.
available, the 7SC80 can obtain and process metering pulses
through an indication input. The metered values can be
displayed and passed on to a control center as an accumulated value with reset. A distinction is made between
8
Binary I/O extension with SICAM I/O-Unit 7XV5673
9
To extend binary inputs and binary outputs for SIPROTEC
7SC80 up to two SICAM I/O-Units 7XV5673 can be added.
Each SICAM I/O-Unit 7XV7653 is equipped with 6 binary
inputs and 6 binary outputs and an Ethernet switch for
cascading. The connection to the protection device can be
either through the DIGSI Ethernet service interface Port A or
through IEC 61850 GOOSE on Port B (System interface with
EN100 module).
10
of operating cycles
at rated normal
current
of operating cycles
breaking current
Commissioning
to prevent unnecessary data from being transmitted.
During commissioning, all indications with test tag for test
purposes can be connected to a control and protection
system.
1
2
3
Test operation
During commissioning, all indications can be passed to a
control system for test purposes.
4
5
6
7
8
9
10
1
2
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,QIHHG
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6XEVWDWLRQ
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%
1
1
1
25
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3
4
25
6WDUWIDXOWLVRODWLRQ
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MGLII
/RDG
1
6WDUWIDXOWLVRODWLRQ
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1
1
1
25
1
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25
6WDUWIDXOWLVRODWLRQ
5
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6
/RDG
1
1
25
7
'LVFRQQHFWLRQ
Fig. 9/14 Ring system application with SIPROTEC 7SC80
8
9
10
6WDUWIDXOWLVRODWLRQ
SNTP-Master/Server SIPROTEC 7SC80
Radial systems
1) Auto-reclosure
(ANSI 79) only with
overhead lines
1
Infeed
2) Unbalanced load
faults
A
2
52
Busbar
52
I>t
IN>t
I2>t
AR
51
51N
46
79
2)
3
1)
Busbar
*
C
4
52
I>t
IN>t
I2>t
51
51N
46
5
Load
Busbar
*
Load
D
52
I>t
IN>t
I2>t
51
51N
46
Load
6
9_9_LSA4839-us.pdf
General hints:
infeed has the shortest tripping
time. Relays further upstream have to
be time-graded against downstream
7
8
9
10
compensated systems
1
measurement of the
be made by a zerosequence current
transformer
Infeed
Busbar
2
52
3
I>>
I>t
50
51
IN>t dir.
7XR96
1)
60/1
67Ns
Load
4
Ring-main cable
6
For lines with infeed from two sources,
no selectivity can be achieved with
a simple definite time-overcurrent
protection. Therefore, the directional
definite time-overcurrent protection
must be used. A non-directional
definite time-overcurrent protection
is enough only in the corresponding
busbar feeders. The grading is done
from the other end respectively.
7
8
Advantage:
9
100% protection of the
line via instantaneous
tripping, and easy
setting.
Infeed
Infeed
52
52
52
I>t
IN>t
ȣ>t
I2>t
51
51N
49
46
Overhead line
or cable 1
Overhead line
or cable 2
I>t
IN>t dir.
I>t
IN>t
67
67N
51
51N
52
Protection as in
the case of line
or cable 1
52
52
52
Disadvantage: Tripping times increase
towards the infeed.
52
67
67N
51
51N
I>t
IN>t dir.
I>t
IN>t
Overhead line
or cable 3
Overhead line
or cable 4
I>t
IN>t dir.
I>t
IN>t
67
67N
51
51N
52
Protection as in
the case of line
or cable 3
52
52
10
52
52
I>t
IN>t
ȣ>t
I2>t
51
51N
49
46
Load
Load
9_10_LSA4841-us.pdf
5
protection, 100 % of the line can be
(ring-main cable).
1
Infeed
I>>t0
50/50N
52
2
51/51N
t0 = 50 ms
Busbar
52
52
I>>
I>t
I>>
I>t
I>>
I>t
50/50N
51/51N
50/50N
51/51N
50/50N
51/51N
3
9_11_LSA4842-us.pdf
52
4
5
In unstable power systems (e.g.
solitary systems, emergency power
supply in hospitals), it may be necessary to isolate selected consumers
from the power system in order to
protect the overall system.
drop.
52
V<
f<
27
81U
7
I>, I>>,
I>>>
IN>>
I>, Ip
IN>,
INTOC
50
50N
51
51N
>
I2>
Final trip
79M
49
46
86
9_12_LSA2216a-us.pdf
The overcurrent protection functions
short-circuit.
6
Busbar
8
9
10
Automatic reclosing
3
4
5
6
infeeds
7
8
9
10
selectively shut down, so that supply
to the busbar is still possible through
the remaining infeed. To do this,
directional devices are required, which
detect a short circuit from the busbar
towards the infeed. In this context, the
directional time-overcurrent protection
is normally adjusted over the load
current. Low-current faults cannot be
shut down by this protection. The reverse
power protection can be adjusted far
below rated power, and is thus also
able to detect reverse power in case of
low-current faults far below the load
current. The reverse power protection
is implemented through the “flexible
protection functions”.
than the fuse or
reclosing for
devices graduated
ON
52
52
TRIP
I>, I>>, I>>>
I>t, I>>t, Ip
50
51
IN>t, IN>>t,
INTOC
IN>>
50N
AR
51N
79
9_13_LSA2219c-us.pdf
2
Stage can
be blocked
52
Fuse opens by
52
I>t, Ip
67
Fig. 9/20 Auto-reclosure
Infeed
A
Infeed
B
52
52
67
67N
32R
67
67N
32R
52
52
52
Feeder
Feeder
9_14_LSA4116-us.pdf
The Automatic reclosing function (AR)
has starting and blocking options. In the
cycles. The overcurrent protection is
graded (stages I, Ip) according to the
grading plan. If an Automatic reclosing
function is installed in the incoming
supply of a feeder, first of all the complete
feeder is tripped instantaneously in case
of fault. Arc faults will be extinguished
independently of the fault location. Other
protection relays or fuses do not trip
(fuse saving scheme). After successful
Automatic reclosing, all consumers are
supplied with energy again. If there is
a permanent fault, further reclosing
cycles will be performed. Depending on
the setting of the AR, the instantaneous
tripping stage in the infeed is blocked in
the first, second or third cycle, i.e., now
the grading is effective according to the
grading plan. Depending on the fault
location, overcurrent relays with faster
grading, fuses, or the relay in the infeed
will trip. Only the part of the feeder with
the permanent fault will be shut down
definitively.
1
Synchrocheck
1
Busbar
V2
52
Closing Signal
1
Transformer
2
Local/remote
control
VT1
4_16_LSA4114-us.pdf
Where two system sections are interconnected, the synchrocheck
determines whether the connection
is permissible without danger to
the stability of the power system. In
the example, load is supplied from
a generator to a busbar through a
transformer. The vector group of
the transformer can be considered
by means of a programmable angle
adjustment, so that no external
adjustment elements are necessary.
Synchrocheck can be used for
auto-reclosure, as well as for control
functions (local or remote).
1)
2
25
SYN
2)
81
G
Infeed
1)
2)
AR
3
Synchrocheck
Automatic reclosing
4
Fig. 9/22 Measurement of busbar and feeder voltage for synchronization
Busbar
High-voltage
5
59-1 PU ,t
59
52
TRIP
I>, I>>
I>t, I>>t, Ip
>t
I2>t, I2>>t
50
51
49
46
IN>, IN>>
IN>t, IN>>t,
INTOC
50N
51N
6
Inrush blocking
7
52
87
e.g.
7UT61
8
52
*
IN>, IN>>
IN>t, IN>>t, INTOC
50N
51N
9
52
Busbar
Medium-voltage
52
52
52
52
TRIP
I2>>t, I2>t I>, I>> I>t, I>>t, Ip
46
50
51
typical Feeder
The high-current stage enables a current grading, the overcurrent stages
work as backup protection to subordinate protection devices, and the overload function protects the transformer from thermal overload.
Low-current, single-phase faults
on the low-voltage side, which are
reproduced in the opposite system
on the high-voltage side, can be
detected with the unbalanced load
protection. The available inrush
blocking prevents pickup caused
by the inrush currents of the
transformer.
10
Unbalanced fault
Description
Order No.
Short code
12345 6 7
1
7SC80
8 9 10 11 12 13 14 15 16
-
-3
17 18 19
–
2
Housing, binary inputs and outputs
Housing, 12 BI, 8 BO, 1 life contact
2
Specification of CT and VT measurement inputs
3
4
3 x I LPS/LoPo, 1 x V 4)
1
4 x I 1 A/5 A, 1 x V
2
3 x I LPS/LoPo, 4 x V 4)
3
4 x I 1 A/5 A, 4 x V
4
3 x I 1A/5A, 1 x Iee (sensitive) = 0,001 to 1,6A/0,005 to 8A, 1 x V
5
3 x I 1A/5A, 1 x Iee (sensitive) = 0,001 to 1,6A/0,005 to 8A, 4 x V
6
DC 60 V to 250 V; AV 115 V; AV 230 V
1
DC 24 V / 48 V
2
DC 24 V/48 V, Battery Monitoring 3)
3
Unit version
5
Surface mounting housing 5)
A
Surface / Flush mounting housing with HMI
B
Surface mounting housing with detached HMI
Region-specifi c default and language settings
6
7
C
2)
A
Region DE, IEC, language German
B
Region World, IEC / ANSI, language English
C
Region US, ANSI, language US-English
E
Region World, IEC / ANSI, language Spanish
C
Region World, IEC/ ANSI, language Russian
E
System interface
8
L
100 Mbit Ethernet, electrical, RJ45 connector
9
R
100 Mbit Ethernet, with integrated switch, optical, 2 x LC connector multimode
9
S
100 Mbit Ethernet, with integrated switch, optical, 2 x LC connector singlemode 24 km
9
T
Protocol for system interface
IEC 61850
0
IEC 61850 + DNP3 TCP
2
IEC 61850 + PROFINET 1)
9
3
IEC 61850 + IEC 60870-5-104
4
Additional interfaces
No module
0
GPS module
7
Functionality
MLFB - number 13, 14, 15, 16 for optional features
10
1) only with 100 Mbit Ethernet electrical and multimode
2) language selectable
3) in preparation
4) The mentioned sensors of SICAM FCM can be used. For protection related purpose the usability of the sensors have to be checked
5) HMI can be ordered separately: without cable: C53207 - A406 - D242 - 1 / with cable:
C53207 - A406 - D243 - 1
see
next
page
ANSI No.
Description
Order No.
Bestell-Nr.
Short code
12345 6 7
7SC80
Software packages
Base Package A
50/51
50N/51N
50N(s)/51N(s)
50BF
46
49
87N
74TC
37
51c
86
60CTS
Time-overcurrent protection phase: I>, I>>, I>>>, Ip
Time-overcurrent protection ground I E >, I E >>, I E >>>, I EP
Sensitive ground fault protection I EE >, I EE >>, I EEp 4)
Negative sequence / unbalanced load protection
Thermal Overload protection
High impedance REF 3)
Undercurrent
Cold load pickup
Lockout
CT supervision
Control of circuit breaker
Under- / overfrequency
Inrush restraint
Fault recording, average values, min/max values
8 9 10 11 12 13 14 15
15 16
16 17 18 19
-
1
–
F A
2
3
4
Base Package B (containing A) 1)
67
67N
67Ns
27/59
81U/O
25
47
64/59N
60VTS
32/55/81R
-3
F B
5
Directional overcurrent protection phase I>, I>>
Directional overcurrent protection ground I E >, I E >>
Directional sensitive ground fault protection I EE >, I EE >>, I EEp 4)
Under- / overvoltage
Under- / overfrequency f< ,f>
Sync-check
Phase rotation
VT supervision
Flexible protection functions (current and voltage parameters)
Protective function for voltage,
power, power factor, frequency change
6
Base Package N (containing R) 2) 5)
7
F N
NTP-server functionality, no protection
Base Package R 2)
F R
pure RTU functionality, no protection
8
Additional functions
Without
0
79
With autoreclose
1
FL
With fault locator 1)
2
79/FL
With autoreclose and fault locator
With single/triple pole autoreclose 1)
3
79/TS
79/TS/FL
With single/triple pole autoreclose and fault locator 1)
9
4
5
10
1) Only with position 7 = 3, 4 or 6
2) Only with position 16 = 0
3) 87N (REF) only with sensitive ground current input (position 7 = 5 oder 6)
4) Depending On the ground current Input the function will be either sensitive (I EE) or Non-sensitive (I E)
5) Only with position 12 = 7
Connection diagrams
72
71
70
69
68
67
66
65
2
BI1
BI2
BI3
BI4
BI5
BI6
BI7
BI8
IC
64
63
62
61
60
59
58
57
3
I A/INs
5
BO2
BO3
BO4
BO5
48
47
46
6
9_Visio-kl-uebers-7sc80-1-us.pdf
7
8
45
44
43
42
41
40
39
38
37
36
35
34
33
BO1
Vx/IA
56
55
54
53
52
51
50
49
4
BI9
BI10
BI11
BI12
IB
BO6
Life Contact
BO7
BO8
+
BAT IN
GPS antenna port
(optional)
Port F
USB-DIGSI-Interface
+
=
(~)
=
Power Supply
Fig. 9/24 Connection diagram SIPROTEC 7SC8021
9
10
HMI-Interface
+
+
+
+
+
+
+
+
-
+
+
+
+
-
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
1
Connection diagrams
IC
IB
IA
64
63
62
61
60
59
58
57
Vx
+
+
+
+
-
BO1
BO3
BO4
BO5
Life Contact
BO6
BO7
BO8
+
BAT IN
GPS antenna port
(optional)
Port F
USB-DIGSI-Interface
+
=
( ~)
=
Power Supply
HMI-Interface
1
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
BO2
48
47
46
34
33
-
BI9
BI10
BI11
BI12
56
55
54
53
52
51
50
49
45
44
43
42
41
40
39
38
37
36
35
+
+
+
+
+
+
+
+
BI1
BI2
BI3
BI4
BI5
BI6
BI7
BI8
2
3
4
5
6
I N, INS
72
71
70
69
68
67
66
65
7
8
Fig. 9/25 Connection diagram SIPROTEC 7SC8022 and SIPROTEC
7SC8025
9
10
Connection diagrams
72
71
70
69
68
67
66
65
2
BI1
BI2
BI3
BI4
BI5
BI6
BI7
BI8
IC
64
63
62
61
60
59
58
57
3
I A/INs
5
6
7
8
34
33
BO2
VC
BO3
VB
BO4
VA
BO5
48
47
46
45
44
43
42
41
40
39
38
37
36
35
BO1
Vx/IA
56
55
54
53
52
51
50
49
4
BI9
BI10
BI11
BI12
IB
BO6
Life Contact
BO7
BO8
+
BAT IN
GPS antenna port
(optional)
Port F
USB-DIGSI-Interface
+
(~)
=
=
Power Supply
HMI-Interface
Fig. 9/26 Connection diagram SIPROTEC 7SC8023
9
10
+
+
+
+
+
+
+
+
-
+
+
+
+
-
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
1
Connection diagrams
1
IC
IB
IA
64
63
62
61
60
59
58
57
Vx
VC
VB
VA
+
+
+
+
-
BO1
Life Contact
BO2
BO3
BO4
BO6
BO7
BO8
+
BAT IN
GPS antenna port
(optional)
Port F
USB-DIGSI-Interface
+
(~)
=
=
Power Supply
HMI-Interface
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
BO5
48
47
46
34
33
-
BI9
BI10
BI11
BI12
56
55
54
53
52
51
50
49
45
44
43
42
41
40
39
38
37
36
35
+
+
+
+
+
+
+
+
BI1
BI2
BI3
BI4
BI5
BI6
BI7
BI8
2
3
4
5
6
I N, INS
72
71
70
69
68
67
66
65
7
8
Fig. 9/27 Connection diagram SIPROTEC 7SC8024 and SIPROTEC
7SC8026
9
10
Connection examples
A
B
C
Standard connection
circuit.
2
52
52
P2
S2
P1
S1
A
3
52
B
F1
IA
F2
F3
IB
F4
F5
IC
F6
IN
F7
C
4_25_LSA4789-en.pdf
1
F8
SIPROTEC
4
A
B
C
A
B
b
5
a
6
52
52
52
VB-N
E12
E13
VC-N
E14
IA
F1
7
l
K
k
A
8
B
F4
IC
F5
L
F2
IB
F3
F6
IN
F7
F8
4_26_LSA4791-en.pdf
VA-N
E9
E11
SIPROTEC
C
Fig. 9/29 Residual current circuit with directional element
For power systems with small earth
currents, e.g. isolated or compensated systems, the earth current is
measured by a zero-sequence current
transformer.
10
52
52
52
F1
F3
F5
L
l
K
k
A
B
C
L
l
K
k
F8
IA
IB
IC
INs
SIPROTEC
F2
F4
F6
F7
9
A
B
C
Fig. 9/30 Sensitive ground current detection without directional element
Connection examples
networks
the V E voltage of the broken delta
A
B
C
A
1
B
da
2
dn
a
52
52
52
E9
VA-B
E11
VC-B
E12
E13
VN
E14
F1
F3
F5
L
l
K
k
A
B
C
L
l
K
k
F8
IA
LSA4792a-en.pdf
b
3
F2
IB
F4
IC
F6
INs
4
F7
5
SIPROTEC
Fig. 9/31 Sensitive directional ground-fault detection with directional element for phases
6
detection.
A
B
C
A
7
B
da
52
52
52
E13
F1
F3
F5
L
l
K
k
A
B
C
L
l
K
k
F8
VN
IA
IB
IC
INs
SIPROTEC
E14
8
F2
F4
F6
F7
9
dn
10
Connection examples
Connection for the synchrocheck
function
If no directional earth-fault protection is used, connection can be
done with just two phase current
transformers. For the directional
phase short-circuit protection, the
phase-to-phase voltages acquired
with two primary transformers are
sufficient.
2
52
52
52
A
B
a
b
VA-B
E9
A
a
B
A
b
a
B
b
E12
VC-B
E11
VSyn
E14
E13
3
IA
F1
4
L
l
K
k
A
B
F2
IB
F3
4_30_LSA4858-en.pdf
1
A
B
C
F4
F5
IC
F8
F7
IN
F8
SIPROTEC
C
Fig. 9/33 Measuring of the busbar voltage and the outgoing feeder
voltage for synchronization
5
6
Transformer connections to three
current transformers and three
voltage transformers
A
B
C
A
7
Busbar
B
a
b
52
52
52
9
10
P2
S2
P1
S1
A
B
C
50
VA
49
52
VB
51
54
VC
53
56
Vx
55
66
IA
65
68
IB
67
70
IC
69
72
IN
SIPROTEC
Fig. 9/34 Transformer connections to three current transformers
and three voltage transformers (phase-to-ground voltages),
normal circuit layout – appropriate for all networks.
71
LSA4792a-en.pdf
8
Connection examples
1
mm 52
mm 52
mm 52
LPCT/LPVT
2
R2
*
*
R1
1)
49
50
59
60
*
VA-N
IA
3
LPCT/LPVT
R2
*
1)
*
R1
51
52
61
62
*
VB-N
IB
4
LPCT/LPVT
1)
R2
*
*
R1
53
54
63
64
VC-N
IC
5
A
B
C
SIPROTEC
9_36 Kombi.pdf
*
6
7
Fig. 9/35 Connection to combined transformer with low-power current-transformer
and integrated voltage divider for the 3 phases
8
9
10
Connection types
1
2
3
4
5
Type of network
Function
Current connection
Voltage connection
networks
Time-overcurrent protection
phase/ground non-directional
–
networks
–
networks
non-directional
–
networks
protection, phase
networks
Directional time- overcurrent
protection, phase
networks
protection, ground-faults
required
Isolated networks
winding
cos ϕ measurement
winding
6
7
8
9
10
Description
The hardware variant of the SIPROTEC 7SC80 integrates an
SNTP server and a GPS module.
1
With it the first substation hardened SNTP server with GPS
receiver is available for precise time synchronization for all
SIPROTEC protection devices and all other SNTP-capable
devices, e.g. SICAM T/Q80 or 3rd-party products.
Protection functions are not provided. The few configuration settings (e.g. IP-address) will be done with DIGSI 4.
2
SIP-COM-05.tif
The communication redundancy protocols RSTP/PRP/
HSR and IEC 61850 are supported completely. With these
features the SNTP Server with optical interfaces can be
operated directly as part of SIPROTEC ring networks.
A GPS antenna kit with antenna, mounting and 25 m cable
is available separately.
3
Funktionsübersicht
• GPS-antenna interface (SMB-connector)
4
• USB-Port for confi guration with DIGSI 4
• Default equipped with 2 electrical Ethernet ports RJ45
• Dual armed connection in Active-Standby confi guration
• Equipped with 2 optical Ethernet interfaces (optional)
• Detached operation possible, with single-mode interfaces up to 24 km
• Complete support of redundant ring structures with
RSTP/PRP/HSR Protocol
• Fulfills EMC requirements in substations
• Extended temperature range -50 °C - +85 °C
• Robust against heavy GOOSE load in IEC 61850 networks
• Can be used as central data concentrator, e.g. recording
of GOOSE messages
• Supports IEC 61850 Edition1 and Edition 2
• Integration in IEC 61850 substation controller (with max.
6 Clients)
• Integration in DIGSI 4 IEC 61850 system confi gurator
• Additional deployment for automation (CFC)
• Remote Access
• Optimized for use together with SIPROTEC devices and
EA-Products
• In accordance with SIPROTEC protective relays.
Fig.9/36 SNTP-Master/Server 7SC80
Applications
5
With the 7SC80 SNTP time server all Ethernet attached
devices can be synchronized via SNTP protocol (Simple
Network Time Protocol) at a millisecond accuracy base.
The transmitted time is standardized UTC-time or local time.
6
For this application all (protection) devices need a suitable
Ethernet interface, e.g. in SIPROTEC 4 port B (EN100
module) is needed.
The GPS antenna is mounted to an outside wall or flat roof
with line of sight to the sky (order separately).
7
The SNTP server will be mounted close to the antenna and
will be typically supplied with the same auxiliary voltage
as the protective relays. By using the optical interfaces,
any EMC influence is excluded, even with long distances
between SNTP Server and protective relays.
8
By using the 7SC80 for time synchronization the typical
accuracy is ±1 ms. A dedicated network for time synchronization is not necessary.
The deployment of 7SC80 in redundant SNTP time server
scenarios is possible as well. The integration in DIGSIprojects can be done with the complete 7SC80 parameter
set; the usage of SNTP.ICD files is no longer necessary.
9
In the protective relays the time source has to be adjusted
to „Ethernet NTP“. Local time settings, e.g. summer/winter
time switchover or time offset, can be considered as well.
10
1
2
3
9_SNTP.eps
4
5
Fig. 9/37 Example of a redundant integration of a 7SC80 SNTP server in an optical SIPROTEC ring network
6
7
Description
Order No.
123456 7
SNTP-Master/Server 7SC80
8
8 ............................... 19
7SC8021-
AB97-3FNO-L0
DC 60 V bis 250 V; AC 115 V; AC 230 V
1
DC 24 V/48 V
2
System interface
9
100 Mbit Ethernet, electical 2 x RJ45 Stecker
R
100 Mbit Ethernet, with integrated switch, optical, 2 x LC connector multi-mode
S
100 Mbit Ethernet, with integrated switch, optical, 2 x LC connector single-mode 24 km
T
GPS antenna kit
7XV5663-0AA00
Indirect lightning protection
7XV5664-0LA00
10
Attachment
SIPROTEC Compact
Attachment
Page
1
2
10/3
10/4
Dimension drawings
10/5
Legal notice
10/7
3
4
5
6
7
8
9
10
Attachment
Ordering example
Position
Description
Order No.
12 3 45 6 7
Short code
1
8 9 10 11 12 13 14 15 16
7RW80 2 0 - 5 E C 9 6 - 1 D A 0 + L 0 G
6
Housing 1/6 19", 3xV, 7 BI, 8 BO1), 1 life contact
8
Rated auxiliary voltage: DC 60 V to 250 V; AC 115 V; AC 230 V
9
10
11
Region US, language US-English, US front, ANSI
Communication: System interface: DNP 3.0, electrical RS485
12
Communication: With Ethernet interface (DIGSI, not IEC 61850), RJ45 connector
13
14 / 15
Protection function: Voltage and frequency relay
1)
2
2
5
E
C
9
L 0G
6
1
3
DA
2 changeover/Form C.
4
Assessories
Product description
Variants
Order No.
DIGSI 4
Basis
7XS5400-0AA00
Software for projecting and usage of all
Siemens protection devices is running under
32 bit and 64 bit
MS Windows XP Professional/
MS Windows 7 Ultimate, Enterprise and
Professional,
MS Windows Server 2008/R2
Basic version with license for 10 computers
(authorisation by serial number)
Professional
DIGSI 4 Basis
+ SIGRA (Fault record analysis)
+ CFC-Editor (Logic-Editor)
+ Display-Editor (Editor for control displays)
+ DIGSI 4 Remote (Remote operation) with license for
10 computers (authorisation by serial number)
7XS5402-0AA00
Professional + IEC 61850
Professional version and IEC 61850
System configurator
with license for 10 computers
(authorisation by serical number)
7XS5403-0AA00
5
6
7
Terminals
Voltage terminal block C or block E
Voltage terminal block D (inverse printed)
Jumper voltage block (6 pice)
C53207-A406-D181-1
C53207-A406-D182-1
C53207-A406-D194-1
Standard USB cable (Typee A-Typee B)
available in specialist stores
Surface console
Mounting bracket set for 19" frame
Accessories for flush-mounted variant perform an
surface-mounted variant
8
C53207-A356-D850-1
C73165-A63-D200-1
9
10
Attachment
Description
1
Order No.
SIGRA 4
Software for graphic visualisation, analysis and evaluation of fault and measurement records
is running under 32- and 64-Bit
MS Windows XP Professional
MS Windows 7
MS Windoxs Server 2008 R2
see product information for supported service packs of operating systems
2
SIGRA 4 for DIGSI
With license for 10 PCs
(authorisation by serial number) For ordering the specification of a DIGSI 4 serial number is required.
7XS5410-0AA00
SIGRA 4 Scientific
3
Installation without DIGSI 4 only for university-level institutions with license for 10 PCs
(authorisation by serial number)
7XS5416-1AA00
Stand Alone Version
Installation without DIGSI 4 (authorisation by serial number)
4
7XS5416-0AA00
Trial SIGRA 4
Like SIGRA 4 Stand Alone, but only valid for 30 days (test version)
(no authorisation required)
7XS5411-1AA00
Upgrade SIGRA 4 Trial to SIGRA 4 Stand Alone
5
Like SIGRA 4 Stand Alone. For customers who want to unlock their trial version.
With license for 10 PCs
6
7
8
9
10
7XS5416-2AA00
Attachment
Dimension drawings
74/2.9
74/2.9
74/2.9
70/2.76
70/2.76
70/2.76
1
Rear view
7RW80
F
Rear view
7SJ80, 7SK80
and 7SD80
SIP C-0019-de.ai
LSA4837a-de.ai
2
Rear view
7SJ81, 7SK81
3
Side view
Front view
Panel cut-out
4
Fig. 10/1 Panel surface and cabinet flush mounting
5
6
7
8
9
192,6
199,1
29,7
251,5
LSA4834a-de.ai
165,1
Side view 7RW80
Fig.10/2 Side views for panel surface mounting
Side view 7SJ8, 7SK8, 7SD80
Front view
10
Note: Dimensions in mm
Values in Brackets in inches
Attachment
Dimension drawings
Dimension drawings SIPROTEC 7SC80
1
Maßbilder 7SC80 side.tif
2
3
4
5
6
7
8
Maßbilder 7SC80 front.tif
9
10
Fig. 10/3 SIPROTEC 7SC80 dimensions
Note: Dimensions in mm
Values in Brackets in inches
Attachment
Legal notice
Indication of conformity
Copyright
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).
Copyright © Siemens AG 2013. All rights reserved.
This conformity has been established by means of tests
conducted by Siemens AG in accordance of the Council
Directive in agreement with the generic standards EN 610006-2 and EN 61000-6-4 for the EMC directives, and with the
standard EN 60255-5 for the low-voltage directive.
The device has been designed and produced for industrial use.
The product is conforming to the international standards of the
series IEC 60255 and the German regulation of VDE 0435.
1
The reproduction, transmission or use of this document or its
contents is not permitted without express written authority.
Offenders will be liable for damages. All rights, including rights
created by patent grant or registration of a utility model or
design, are reserved.
2
Registered trademarks
SIMATIC®, SIMATIC NET®, SIPROTEC®, DIGSI®, SIMEAS® ,
SICAM® and SINAUT® are registered trademarks of SIEMENS
AG. All other product and brand names in this manual might be
trademarks, the use of which by third persons for their purposes might infringe the rights of their respective owners.
3
Disclaimer of liability
4
This document has been subjected to rigorous technical review
before being published. It is revised at regular intervals, and
any modifications and amendments are included in the subsequent issues. 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, Siemens AG shall not assume any liability for defects
and damage which result through use of the information
contained herein.
5
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.
6
Document version: 03
Release status: 12.2013
7
Version of the product described: V4.x
8
9
10
*
Published by and copyright © 2014:
Siemens AG
Infrastructure & Cities Sector
Smart Grid Division
Energy Automation
Humboldtstr. 59
90459 Nuremberg
Germany
All rights reserved.
If not stated otherwise on the individual pages of this
catalog, we reserve the right to include modifications,
especially regarding the stated values, dimensions and weights.
Drawings are not binding.
All product designations used are trademarks or product
names of Siemens AG or other suppliers.
If not stated otherwise, all dimensions in this
catalog are given in mm (inch).
Subject to change without prior notice.
The information in this document contains general
descriptions of the technical Optionals available, which
may not apply in all cases. The required technical
Optionals should therefore be specified in the contract.
For all products using security features of OpenSSL the following shall apply:
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
([email protected])
For more information,
Order No. IC1000-K4403-A011-A3-7600
please contact our
Printed in Germany
Customer Support Center.
Dispo 06200
Tel.: +49 180 524 84 37
KG 01.14 1.6 210 En
Fax: +49 180 524 24 71
E02018413 HHGlobal
(Charges depending on provider)
Printed on elementary chlorine-free bleached paper.
E-Mail: [email protected]
www.siemens.com/siprotec

SIPROTEC Compact 7SD80, 7SJ80, 7SJ81, 7SK80, 7SK81, 7RW80

Transcription

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