Siprotec Compact Catalog en

SIPROTEC Compact
Perfect Protection – smallest space

7SD80, 7SJ80, 7SJ81, 7SK80, 7SK81,
7RW80, 7SC80
Catalog • Edition 5
siemens.com/siprotec
Overview of Documentation
Documentation
SIPROTEC
SIPROTEC 5 SIPROTEC 4
Compact
Catalog Catalog Catalog
Manuals Manuals Manuals
SICAM SICAM
Power quality Substation Accessories Reyrolle
and automation
measurement Catalog Catalogs
Catalog Catalog
Manuals Manuals Manuals Manuals
Fig. 1/1 Overview of Siemens protection catalogs
SIPROTEC Compact catalog SICAM Power Quality and Measurement catalog

The catalog describes the features of the SIPROTEC Compact This catalog gives an overview of the power quality and
series and presents the available devices and their applica- measurement devices, applications and features.
tion possibilities.
SICAM Substation Automation catalog
SIPROTEC 5 catalog
This catalog gives an overview of the product devices, ap-
The catalog describes the system features and the devices plications and features.
of SIPROTEC 5.
Accessories catalog
SIPROTEC 4 catalog
This catalog describes the accesories for protection, power
This catalog describes the features of the device series quality and substation automation devices.
SIPROTEC 4.
Reyrolle catalog
This catalog gives an overvoew of the Reyrolle devices and
features.
Manuals
The manuals describe, among others, the operation, instal-
lation, the technical data of the devices.
Contents
SIPROTEC Compact Introduction Page
7SD80, 7SJ80, 7SJ81,

Editorial
Overview of all SIPROTEC device series
1/4
1/5 to 1/8 11
7SK80, 7SK81, 7RW80, SIPROTEC Compact
7SC80 Selection table, system features,

operating programs 2/1 to 2/16
22
Products
Catalog SIP 3.01 · Edition 5
Line Differential Protection SIPROTEC 7SD80
Invalid: C
atalog SIP 3.01 · Edition 4
3/1 to 3/22
33
www.siemens.com/protection
Overcurrent Protection SIPROTEC 7SJ80
4/1 to 4/30
44
for Low-Power Current Transformer Applications
5/1 to 5/22 55
Generator and Motor Protection SIPROTEC 7SK80
6/1 to 6/28
66
for Low-Power Current Transformer Applications
7/1 to 7/26 77
Voltage and Frequency Protection SIPROTEC 7RW80
8/1 to 8/16
88
Feeder Protection SIPROTEC 7SC80
9/1 to 9/36
99
Attachment
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 5 1/3

Introduction
Editorial
We are pleased to have the opportunity to introduce our

SIPROTEC Compact catalog to you.
1 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
2 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.
3 The Compact series fits perfectly into the SIPROTEC concept,
LSP3.01-0001.eps
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
4 supply systems.
Fig. 1/2 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.
5 Please convince yourself of the performance of SIPROTEC

Compact series, and develop the possible solutions for your
requirements.
SIPROTEC – safe, reliable and efficient.
6
Smart Infrastructure
Digital Grid
Energy Automation
7
LSP3.01-0002.eps
Municipal_utilities.tif
8
Fig. 1/3 Application in medium voltage
10
1/4 SIPROTEC Compact · SIEMENS SIP 3.01 · Edition 5

Introduction
SIPROTEC device series
Solutions for today‘s and future power supply systems –

for more than 100 years
SIPROTEC has established itself on the energy market for 1

decades as a powerful and complete system family of
numerical protection relays and bay controllers from
Siemens.
SIPROTEC protection relays from Siemens can be consis-
tently used throughout all applications in medium and high
2
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
3
LSP3.01-0003.eps
duties – because SIPROTEC stands for continuity, openness
and future-proof design.
As the innovation driver and trendsetter in the field of
protection systems for more than 100 years, Siemens helps
system operators to design their grids in an intelligent, eco-
logical, reliable and efficient way, and to operate them eco-
Fig. 1/4 SIPROTEC family
4
nomically. As a pioneer, Siemens has decisively influenced
the development of numerical protection systems (Fig. 1/5). How can system operators benefit from this experience?
The first application went into operation in Würzburg, • Proven and complete applications
Germany, in 1977. Consistent integration of protection and
control functions for all SIPROTEC devices was the innova-
• Easy integration into your system
• Highest quality of hardware and functionality
5
tion step in the 90ies. After release of the communication
standard IEC 61850 in the year 2004, S iemens was the first • Excellent operator friendliness of devices and tools
manufacturer worldwide to put a system with this com- • Easy data exchange between applications
munication standard into operation. In the meantime we
have delivered more than 500,000 devices with IEC 61850
• Extraordinary consistency between product and
system-engineering 6
included. • Reduced complexity by easy operation
Many users have approved SIPROTEC protection devices • Siemens as a reliable, worldwide operating partner.
for use in their power systems. The devices have also been
certified by independent test institutes and universities
(KEMA, EPRI, LOYD, UR Laboratories). Information about the SIPROTEC 4 and SIPROTEC 5 product 7
families can be found in the related catalogs or at:
www.siemens.com/siprotec
10
LSP3.01-0004-en.eps
Fig. 1/5 SIPROTEC – Pioneer over generations

Introduction
SIPROTEC 5 – the new benchmark for protection,

automation and monitoring of grids
1 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 func-
tionalities and device types. With the holistic and consistent
2 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
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
3 continuously changing requirements throughout the entire
life cycle.
Besides the reliable and selective protection and the com-
plete automation function, SIPROTEC 5 offers an extensive
database for operation and monitoring of modern power
4 supply systems. Synchrophasors (PMU), power quality data
Fig. 1/6 SIPROTEC 5 – modular hardware
and extensive operational equipment data are part of the

scope of supply.
• Powerful protection functions guarantee the safety of the
5 system operator‘s equipment and employees

• Individually configurable devices save money on initial in-
vestment as well as storage of spare parts, maintenance,
expansion and adjustment of your equipment
• Arc protection, detection of transient ground fault and
6 process bus simply integrable and retrofittable
• Clear and easy-to-use of devices and software thanks to
LSP3.01-0014.eps
user-friendly design
• Increase of reliability and quality of the engineering
7 process
• High safety by consistent implementation of Safety and
Security
• Powerful communication components guarantee safe and
effective solutions
8 • Full compatibility between IEC 61850 Editions 1 and 2
Fig. 1/7 SIPROTEC 5 – modular process connection
• Integrated switch for low-cost and redundant optical and

electrical Ethernet rings
• Ethernet redundancy protocols RSTP, PRP and HSR for
9 highest availability
• Efficient operating concepts by flexible engineering of
IEC 61850 Edition 2
• C
omprehensive database for monitoring of modern power
grids
• Optimal smart automation platform for grids based on
integrated synchrophasor measurement units (PMU) and
power quality functions.
10
LSP3.01-0012.eps
Fig. 1/8 Application in a high-voltage power system

Introduction
SIPROTEC Compact –
Maximum protection – minimum space
Reliable and flexible protection for energy distribution and 1
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 pro-
tection in medium-voltage applications or as back-up pro- 2
tection in high-voltage systems.
LSP3.01-0007-en.eps
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. 3
The SIPROTEC Compact series is based on millions of opera-
tional 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.
Fig. 1/9 SIPROTEC Compact
4
• Simple installation by means of pluggable current and
voltage terminal blocks
• Thresholds adjustable via software (3 stages guarantee a
safe and reliable recording of input signals)
• Easy adjustment of secondary current transformer values
5
(1 A/5 A) to primary transformers via DIGSI 4
• Quick operations at the device by means of 9 freely
programmable function keys
• Clear overview with six-line display 6
LSP3.01-0008.eps
• E
asy 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 7
two further communication interfaces
• Integrated switch for low-cost and redundant optical
Ethernet rings
highest availability
Fig. 1/10 SIPROTEC Compact – rear view
8
• Reduction of wiring between devices by means of cross-
communication via Ethernet (IEC 61850 GOOSE)
• T
ime synchronization to the millisecond via Ethernet with
SNTP for targeted fault evaluation 9
• Adjustable to the protection requirements by means of
“flexible protection functions”
• Comfortable engineering and evaluation via DIGSI 4.
7SC80 mit HMI.png
10
Fig. 1/11 Feeder Protection SIPROTEC 7SC80 with HMI

Introduction
SIPROTEC 4 – the proven, reliable and future-proof

protection for all applications
1 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,
2 the SIPROTEC 4 device family has gained the highest ap-

preciation 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.
3
LSP3.01-0010.eps
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
4 tasks of the secondary systems can be performed with one

single device. The open and future-proof concept of
Fig. 1/12 SIPROTEC 4
SIPROTEC 4 has been ensured for the entire device series

with the implementation of IEC 61850.
• Proven protection functions guarantee the safety of the
5 systems operator‘s equipment and employees
• Comfortable engineering and evaluation via DIGSI 4
• S
imple creation of automation solutions by means of the
integrated CFC
6 • Targeted and easy operation of devices and software

thanks to user-friendly design
• P
owerful communication components guarantee safe and
LSP2174-afp.tif
effective solutions
• Maximum experience worldwide in the use of SIPROTEC 4
7 and in the implementation of IEC 61850 projects
• Future-proof due to exchangeable communication inter-
faces and integrated CFC
8 Ethernet rings
Fig. 1/13 SIPROTEC 4 – rear view
highest availability.
10
LSP3.01-0011.eps
Fig. 1/14 SIPROTEC 4 application in power stations

Introduction
10

Introduction
10

Protection Systems
SIPROTEC Compact
Protection Systems – SIPROTEC Compact
Seite
1
SIPROTEC Compact selection table 2/3
SIPROTEC Compact system features 2/5
2 Operation 2/7
Construction and hardware 2/8
Control and automation functions 2/9
Operating programs DIGSI 4 and SIGRA 4 2/10
3 Communication 2/13
10

SIPROTEC Compact selection table
Overcurrent
Voltage and
differential
basic
and feeder
protection
protection
protection
protection
protection
and motor
Generator
frequency
optional
1
Feeder
– not available
Line
1) in preparation
SIPROTEC Compact
7RW80
7SD80
7SK80
7SK81
7SC80
7SJ80
7SJ81
ANSI Siemens function Abbr. 2
Protection functions for 3-pole tripping 3-pole ◾ ◾ ◾ ◾ ◾ ◾ ◾
Protection functions for 1-pole tripping 1-pole – – – – – – ●
14 Locked rotor protection I> + V< – – – ◾ ◾ – –
FL Fault locator FL – ● ● – – – ●
24 Overexcitation protection V/f – – – – – ● –
25 Synchrocheck, synchronizing function Sync – ● – – – ● ●
27 Undervoltage protection
Undervoltage-controlled reactive power protection
V<
Q>, V>
●
–
●
●
●
–
●
–
●
–
◾
–
●
–
3
32 Directional power supervision P<>, Q<> – ● ● ● ● – ●
37 Undercurrent protection, underpower I<, P< – ◾ ◾ ◾ ◾ – ◾
38 Temperature supervision θ> – – – ◾ ◾ – –
◾ ◾ ◾ ◾ ◾
46
46
Unbalanced-load protection
Negative-sequence system overcurrent protection
I2>
I2>, I2/I1>
–
– ◾ ◾ ◾ ◾
–
– ◾ 4
47 Phase-sequence-voltage supervision LA, LB, LC – ● ● ● ● ◾ ●
47 Overvoltage protection, negative-sequence system V2> ● ● ● ● ● ◾ ●
48 Starting-time supervision I2start – – – ◾ ◾ – –
49 Thermal overload protection θ, I2t ◾ ◾ ◾ ◾ ◾ – ◾
◾ ◾ ◾ ◾ ◾ ◾
50/50N
SOFT
Definite time-overcurrent protection
Instantaneous tripping at switch onto fault
I>
◾ ◾ ◾ ◾ ◾ ◾
–
◾ 5
50Ns Sensitive ground-current protection INs> – ● ● ● ● – ◾
Intermittent ground-fault protection Iie> – ◾ – ◾ – – –
50L Load-jam protection I>L – – – ◾ ◾ – –
50BF Circuit-breaker failure protection CBFP ◾ ◾ ◾ ◾ ◾ – ◾
51C
51/51N
Cold load pickup
Inverse time-overcurrent protection IP, INP ◾
– ◾
◾
◾
◾
◾
◾
◾
◾
–
–
◾
◾
6
51V Voltage dependent overcurrent protection t=f(I)+V< – ● – ● – – ●
55 Power factor cos j – ● ● ● ● – ●
59 Overvoltage protection V> ● ● ● ● ● ◾ ●
● ● ● ● ● ◾ ●
7
59N Overvoltage protection, zero-sequence system V0>
59R, 27R Rate-of-voltage-change protection dV/dt – ● – ● – ◾ ●
60FL Measuring-voltage failure detection ● ● ● ● ● – ●
66 Restart inhibit I 2t – – – ◾ ◾ – –
67 Directional time-overcurrent protection, phase I>, IP ∠ (V,I) ● ● ● – – – ●
67N Dir.time-overcurrent protection for ground-faults IN>, INP ∠ (V,I) ● ● ● ● ● – ●
67Ns
Dir. sensitive ground-fault detection for systems
with resonant or isolated neutral
INs ∠ (V,I) – ● ● ● ● – ● 8
Directional intermittent ground fault protection Iie dir> – ● – ● – – –
74TC Trip-circuit supervision TCS ◾ ◾ ◾ ◾ ◾ ◾ ◾
79 Automatic reclosing AR ● ● ● – – – ●
81 Frequency protection f<, f> ● ● ● ● ● ◾ ●
81R Rate-of-frequency-change protection
Vector-jump protection
df/dt
∆ϕU>
●
–
●
–
●
–
●
–
●
–
◾
●
●
–
9
81LR Load restoration LR – – – – – ● –
85 Teleprotection ◾ – – – – – –
86 Lockout ◾ ◾ ◾ ◾ ◾ ◾ ◾
87 Differential protection ΔI ◾ – – – – – –
87N Differential ground-fault protection ΔIN ◾ ● – – – – ◾
Broken-wire detection for differential protection ◾ – – – – – –
Further functions see next page
10

SIPROTEC Compact selection table
Overcurrent
Voltage and
differential
basic
and feeder
protection
protection
protection
protection
protection
and motor
Generator
frequency
1 optional
Feeder
– not available
Line
1) in preparation
SIPROTEC Compact
7RW80
7SD80
7SK80
7SK81
7SC80
7SJ80
7SJ81
2 ANSI Siemens function Abbr.
Further functions
Measured values ◾ ◾ ◾ ◾ ◾ ◾ ◾
Switching-statistic counters ◾ ◾ ◾ ◾ ◾ ◾ ◾
Circuit breaker wear monitoring ΣIx, I2t, 2P – – – – – – ◾
Logic editor ◾ ◾ ◾ ◾ ◾ ◾ ◾
Inrush-current detection ◾ ◾ ◾ ◾ ◾ – ◾
3 External trip initiation
Control
◾
◾
◾
◾
◾
◾
◾
◾
◾
◾
◾
◾
◾
◾
Fault recording of analog and binary signals ◾ ◾ ◾ ◾ ◾ ◾ ◾
Monitoring and supervision ◾ ◾ ◾ ◾ ◾ ◾ ◾
Protection interface, serial ◾ – – – – – –
4 No. Setting groups

Changeover of setting group ◾
4
◾
4 4
◾ ◾
4 4
◾ ◾
4 16
◾
Circuit breaker test ◾ – – – – – –
Easy Protection Device Selector
5 Table 2/1 SIPROTEC Compact relay selection table
10

SIPROTEC Compact system features
Field devices in energy distribution systems and in industrial Fig. 2/1 shows exemplary how the most different tasks can
applications must cover the most varying tasks, and yet be be easily and safely solved with the matching
adjustable easily and at short notice. These tasks comprise,
for example:
SIPROTEC Compact devices.
1
Operation
• Protection of different operational equipment such as
lines, cables, motors and busbars During the development of SIPROTEC Compact, special value
was placed not only on a powerful functionality, but also on
• D
ecoupling and disconnecting of parts of the power
supply system
simple and intuitive operation by the operating personnel.
Freely assignable LEDs and a six-line display guarantee an
2
• Load shedding and load restoration unambiguous and clear indication of the process states.
• Voltage and frequency protection In conjunction with up to 9 function keys and the control
• Local or remote control of circuit-breakers keys for the operational equipment, the operating personnel
• Acquisition and recording of measured values and events can react quickly and safely to every situation. This ensures
• Communication with neighboring devices or the control
center.
a high operational reliability even under stress situations,
thus reducing the training effort considerably. 3
5
Infeed
7SJ80 7RW80
6
SIEMENS
Backup transformer SIEMENS
52 Voltage/frequency protection
protection
Load shedding
Busbar protection via
Load restoration
reverse interlocking
MV-Substation
7
52 7SD80 52 7SJ80 52
7SJ80 52
7SC80 52 7SK80 7SJ80
SIEMENS
Busbar protection via SIEMENS SIEMENS SIEMENS 52 SIEMENS
reverse interlocking
possible
8
G M 9
7SD80 7RW80 7SK80
SIEMENS SIEMENS SIEMENS
1_17_Visio_Compact.pdf
52 52
Cable Generation Transformer Feeder Motor Bus Coupler 10
Fig. 2/1 Fields of application in a typical MV system

SIPROTEC Compact system features
Feeder Protection SIPROTEC 7SC80 Load balancing

The Feeder Automation device SIPROTEC 7SC80 is designed Balance the load within a feeder by moving the disconnec-
1 for decentralized as well as for centralized feeder automa-
tion applications. This solution allows various flexible high
tion.
Activation of individual line sections
speed applications like
Isolate a dedicated section of a feeder for maintenance
FLISR (Fault Location, Isolation, and Service Restoration) without affecting other sections. Fig. 2/2 shows an example
2 Detect and locate a fault in the feeder, isolate the faulty

section and set the healthy portions of the feeder back into
of a typical ring main application with overhead lines and 5
sections. Every section is protected and automated by the
SIPROTEC 7SC80 Feeder Protection.
service
Source transfer
Detect and isolate a faulty source and set the de-energised
3 sections of the feeder back into service
6 Substation
A
Substation
B
7 52 52
50/50N 50/50N
OR Start fault isolation OR Start fault isolation
Current-jump detection Current-jump detection
8
Communication network
52 52
9
50/50N 50/50N
50/50N
OR Start fault isolation
Current-jump detection
10
52
Fig. 2/2 Fields of application with feeder protection SIPROTEC 7SC80

Operation
Local operation
All operations and information can be executed
via an integrated user interface: 1
2 operation LEDs
In an illuminated 6-line LC display, process and

2
device information can be indicated as text in
different lists.
4 navigation keys
8 freely programmable LEDs serve for indication 3

of process or device information. The LEDs can
be labeled user-specifically. The LED reset key
resets the LEDs.
4
9 freely configurable function keys
support the user in performing frequent
operations quickly and comfortably. 5
LSP2899.eps
Fig. 2/3
SIPROTEC Compact
Numerical operation keys with open board
USB user interface (type B) for modern

6
and fast communication with the
operating software DIGSI.
Keys “O” and “I” for direct control of

operational equipment.
7
9
LSP2900.eps
10
Fig. 2/4
SIPROTEC Compact
Battery cover accessible from outside.
with closed board and
open battery cover

Construction and hardware
Connection techniques and housing with

many advantages
1 The relay housing is 1/6 of a 19" rack and
LSP3.01-0033.eps
makes replacement of predecessors model
very easy. The height is 244 mm (9.61").
Pluggable current and voltage terminals
2 allow for pre-wiring and simplify the

exchange of devices in the case of support.
Fig. 2/6 Voltage terminal block
CT shorting is done in the removable current

terminal block. It is thus not possible to open-
LSP3.01-0008.eps
circuit a secondary current transformer.
All binary inputs are independent and
LSP3.01-0034.eps
the pick-up thresholds are settable using
3 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
Fig. 2/5 7SK80, 7SJ80, 7SD80 Fig. 2/7 Current terminal block
entries, switching sequences, etc. The as-
4 signed function of the function keys can be
rear view
shown in the display of the relay.

With overcurrent protection SIPROTEC 7SJ81
there is also a device for low-power current
5 transformer applications.
Current terminals – ring-type lugs
Connection Wmax = 9.5 mm
6 Ring-type lugs d1 = 5.0 mm

LSP3.01-0015.eps
LSP3.01-0016.eps
Wire size 2.0 – 5.2 mm2 (AWG 14 – 10)
Current terminals – single cables
Cable cross-section 2.0 – 5.2 mm2 (AWG 14 – 10)
7 Conductor sleeve with
plastic sleeve
L = 10 mm (0.39 in) or
L = 12 mm (0.47 in)
Stripping length 15 mm (0.59 in)
(when used without Only solid copper wires may
conductor sleeve) be used. Fig. 2/8 7SJ81, 7SK81 rear view Fig. 2/9 7RW80 rear view
8 Voltage terminals – single cables

Cable cross-section 0.5 – 2.0 mm2 (AWG 20 – 14)
Conductor sleeve with L = 12 mm (0.47 in)
plastic sleeve
Stripping length 12 mm (0.427 in)
9 (when used without
conductor sleeve)
Only solid copper wires may
be used. w
Table 2/2 Wiring specifications for process connection
SIP C-0002.ai
d1
Fig. 2/11 Ring-type lug

LSP2901.eps
10
Fig. 2/10 Front view,
surface-mounting housing

Control and automation functions
Control Assignment of feedback to command

In addition to the protection functions, SIPROTEC Compact The positions of the circuit-breaker or switching devices
units also support all control and monitoring functions that and transformer taps are acquired through feedback. These 1
are required for operating medium-voltage or high-voltage indication inputs are logically assigned to the corresponding
substations. The status of primary equipment or auxiliary command outputs. The unit can therefore distinguish
devices can be obtained from auxiliary contacts and com- whether the indication change is a result of switching
municated to the unit via binary inputs. Therefore it is operation or whether it is an undesired spontaneous change
possible to detect and indicate both the OPEN and CLOSED of state. 2
position or a fault or intermediate circuit-breaker or auxiliary
contact position. Chatter disable
The switchgear or circuit-breaker can be controlled via: The chatter disable feature evaluates whether, in a set
–– integrated operator panel period of time, the number of status changes of indication
input exceeds a specified number. If exceeded, the indica-
–– binary inputs
–– substation control and protection system
tion input is blocked for a certain period, so that the event
list will not record excessive operations.
3
–– DIGSI 4.
Indication filtering and delay
Automation / user-defined logic
Binary indications can be filtered or delayed. Filtering serves
With integrated logic, the user can create, through a graphic to suppress brief changes in potential at the indication 4
interface (CFC), specific functions for the automation of a input. The indication is passed on only if the indication
switchgear or a substation. Functions are activated using voltage is still present after a set period of time. In the event
function keys, a binary input or through the communication of an indication delay, there is a delay for a preset time. The
interface. information is passed on only if the indication voltage is still
Switching authority
present after this time. 5
Indication derivation
Switching authority is determined by set parameters or
through communications to the relay. Each switching User-definable indications can be derived from individual
operation and switch-position change will be noted in the
operational log. Command source, switching device, cause
or a group of indications. These grouped indications are of
great value to the user that need to minimize the number of 6
(spontaneous change or command) and result of indications sent to the system interface.
a switching operation will be stored.
Command processing
All functionalities of the command processing are available.
7
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
8
output. Here are some typical applications:
• Single and double commands using 1, 1 plus 1 common
or 2 trip contacts
• User-definable bay interlocks 9
• Operating sequences combining several switching opera-
tions, such as control of circuit-breakers, disconnectors
and grounding switches
• Triggering of switching operations, indications or alarms
by combination with existing information.
10

Operating programs DIGSI 4 and SIGRA 4
DIGSI 4, an operating software for

all SIPROTEC protection devices
1 The PC operating program DIGSI 4 is the user interface With DIGSI 4, SIPROTEC devices are configured and evalu-
to the SIPROTEC devices, regardless of their version. It is ated – it is the tailored program for industrial and energy
designed with a modern, intuitive user interface. distribution systems.
Fig. 2/12 DIGSI 4 operating program
10

Simple protection setting

From the numerous protection
functions it is possible to easily select 1
only those which are really required
(see Fig. 2/13). This increases the
clearness of the other menus.
Device setting with primary or

secondary values
2
The settings can be entered and
displayed as primary or secondary
values. Switching over between
primary and secondary values is done
LSP3.01-0017.eps
with one mouse click in the tool bar
(see Fig. 2/13).
3
Assignment matrix
Fig. 2/13 DIGSI 4, main menu, selection of protection functions
The DIGSI 4 matrix shows the user
the complete configuration of the 4
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 5
changed.
LSP3.01-0018.eps
IEC 61850 system configurator
The IEC 61850 system configurator,
which is started out of the system 6
manager, is used to determine the Fig. 2/14 DIGSI 4, assignment matrix
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 7
in the “network” working area – if
required –, available participants
are assigned to the subnets, and ad-
dressing is defined. The “assignment”
working area is used to link data 8
objects between the participants, e.g.,
the starting message of the V /inverse
time-overcurrent protection I > func-
tion of feeder 1, which is transferred
to the incoming supply in order to 9
prompt the reverse interlocking of the
V / inverse time-overcurrent protection
I >> function there (see Fig. 2/15).
System Configurator.tif
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
2 sequences.
Logical elements such as AND, OR,
timers, etc., as well as limit value re-
quests of measured values are available
(Fig. 2/16).
3 Commissioning
LSP2324-afpen.tif
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
4 wiring test is possible. Messages can Fig. 2/16 CFC plan
be sent to the serial interface delibe-
rately for test purposes.
SIGRA 4, powerful analysis of all

5 protection fault records
lt is of crucial importance after a line
fault that the fault is quickly and fully
analyzed so that the proper measures
6 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
7 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.
LSP2330-afpen.tif
8 FASE and FAST: Convenient
engineering and test tool for Feeder
Automation Applications
FASE is a standalone engineering
9
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 P01 A P02 B P03 C P04 D P05 S2
DIGSI parameter set files, engineers can
use defined templates to create the MV E P06
topology graphically via drag&drop.
FASE offers as well an editable table S3 P07 F P08 G P09 H P10 I P11 S4
with most relevant protection and
10 communication settings of all SIPROTEC
7SC80 devices at a glance.
J P12
Within FASE you can create flexible

sequences step by step for several S5 P13 K P14 L P15 P16 M P17 S6
applications with the graphical user
interface. Bild 2/18 FASE configuration

Communication
Communication System interface protocols (retrofittable)

As regards communication, the devices offer high flexibility • IEC 61850
for the connection to industrial and energy automation The ethernet-based protocol IEC 61850 is established as 1
standards. The concept of the communication modules a worldwide standard for protection and systems control.
running the protocols enables exchangeability and retrofit- SIPROTEC devices work as IEC 61850 servers and, via the
tability. Thus, the devices can also be perfectly adjusted to a protocol, they can exchange extensive data with up to 6
changing communication infrastructure in the future, e.g., clients (e.g. SICAM PAS) which are defined in logical nodes
when Ethernet networks will be increasingly used in the in the IEC 61850 Standard for protection and systems 2
utilities sector in the years to come. control functions. Static and dynamic reports are supported.
Additionally, fault records can be transmitted which are
USB interface stored in the binary Comtrade format in the device. Switch-
There is a USB interface on the front of the relay. All the ing commands can be executed in the controlling direction.
relay functions can be parameterized on PC by using DIGSI- Data can be transmitted within few milliseconds between
programs. Commissioning tools and fault analysis are built
into the DIGSI program and are used through this interface.
devices via GOOSE messages of the IEC 61850. This efficient
intercommunication between devices replaces the former
3
parallel wiring through communication connections via the
Interfaces ethernet network.
A number of communication modules suitable for various IEC 61850 is supported in Edition 1 and Edition 2 and the
applications can be fitted at the bottom of the housing. devices are certified independently in compliance with
IEC 61850 Part 10.
4
The modules can be easily replaced by the user. The inter-
face modules support the following applications: The time synchronization can be made redundantly via
• System/service interface two SNTP timers which are integrated in the IEC 61850
engineering.
Communication with a central control system takes place
through this interface. Radial or ring type station bus In addition to the IEC 61850 protocol, further protocols are 5
topologies can be configured depending on the chosen in- available on the ethernet module. They can be activated and
terface. Furthermore, the units can exchange data through deactivated through DIGSI 4 so that safety requirements are
this interface via Ethernet and the IEC 61850 protocol and fulfilled. The devices can be accessed completely with DIGSI 4
can also be accessed using DIGSI. Alternatively, up to 2 ex-
ternal temperature detection devices with max. 12 metering
via the ethernet network with the ethernet module. Diag-
nostic pages of the module can be accessed via a browser, 6
sensors can be connected to the system/service interface. e.g. for supporting the commissioning. The device can be
• Ethernet interface integrated into a network monitoring system via SNMP V2
The Ethernet interface has been designed for quick access to which allows monitoring permanently the behavior of the
several protection devices via DIGSI. In the case of the motor
protection 7SK80, it is possible to connect max. 2 external
device in the network. The network redundancy protocols
RSTP and HSR which are integrated on the ethernet module 7
temperature detection devices with max. 12 metering permit the construction of economical ring structures.
sensors to the Ethernet interface. As for the line differential Interruption-free redundancy can be achieved via parallel
protection, the optical interface is located at this interface. networks with PRP.
10

Communication
• IEC 60870-5-103 The time synchronization is performed via the DNPi client
The IEC 60870-5-103 protocol is an international standard or SNTP. The device can also be integrated into a network
1 for the transmission of protective data and fault recordings.
All messages from the unit and also control commands can
monitoring system via the SNMP V2 protocol.
Parallel to the DNP3 TCP protocol the IEC 61850 protocol
be transferred by means of published, Siemens-specific (the device works as a server) and the GOOSE messages
extensions to the protocol. of the IEC 61850 are available for the intercommunication
Optionally, a redundant IEC 60870-5-103 module is avail- between devices.
2 able. This redundant module allows to read and change
individual parameters.
• PROFINET
PROFINET is the ethernet-based successor of Profibus DP
• IEC 60870-5-104
and is supported in the variant PROFINET IO. The protocol
The IEC 60870-5-104 substation and power system which is used in industry together with the SIMATIC systems
automation protocol is supported via the electrical and control is realized on the optical and electrical Plus ethernet
optical Ethernet module. Indications (single and double), modules which are delivered from November 2012. All
3 measured values, metered values can be transmitted to one
or two (redundant) masters. IEC 104 file transfer is also
network redundancy procedures which are available for
the ethernet modules, such as RSTP, PRP or HSR, are also
supported and fault recordings can be read out of the device available for PROFINET. The time synchronization is made
in Comtrade format. In the command direction, secured via SNTP. The network monitoring is possible via SNMP V2
switching of switching objects is possible via the protocol. where special MIB files exist for PROFINET. The LLDP protocol
4 Time synchronization can be supported via the
IEC 60870-5-104 master or via SNTP across the network. Re-
of the device also supports the monitoring of the network
topology. Single-point indications, double-point indications,
dundant time servers are supported. All auxiliary services on measured and metered values can be transmitted cyclically
Ethernet such as the DIGSI 5 protocol, network redundancy, in the monitoring direction via the protocol and can be
or SNMP for network monitoring can be activated concur- selected by the user with DIGSI 4. Important events are also
5 rently with IEC 60870-5-104. Moreover, GOOSE messages of
IEC 61850 can be exchanged between devices.
transmitted spontaneously via configurable process alarms.
Switching commands can be executed by the system control
• PROFIBUS-DP via the device in the controlling direction.
PROFIBUS-DP is a widespread protocol in industrial automa- The PROFINET implementation is certified.
tion. Through PROFIBUS-DP, SIPROTEC units make their
6 information available to a SIMATIC controller or receive com-
mands from a central SIMATIC controller or PLC. Measured
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
values can also be transferred to a PLC master.
intercommunication between devices, e.g. for transmitting
• MODBUS RTU fault records and GOOSE messages.
This simple, serial protocol is mainly used in industry and
7 by power utilities, and is supported by a number of relay
• Redundancy protocols for Ethernet (RSTP, PRP and HSR
SIPROTEC Compact supports the redundancy protocols RSTP,
manufacturers. SIPROTEC units function as MODBUS slaves,
making their information available to a master or receiving PRP and HSR. These protocols can be loaded and activated
information from it. A time-stamped event list is available. easily via software on the existing optical Ethernet modules.
PRP and HSR guarantee a redundant, uninterruptible and
8 • DNP 3.0 protocol
Power utilities use the serial DNP 3.0 (Distributed Network
seamless data transfer in Ethernet networks without exten-
sive parameter settings in the switches.
Protocol) for the station and network control levels.
SIPROTEC units function as DNP slaves, supplying their infor-
mation to a master system or receiving information from it.
9 • DNP3 TCP
The ethernet-based TCP variant of the DNP3 protocol is sup-
ported 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 indica-
tions, measured and metered values can be configured with
10 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.

Communication
System solutions
IEC 60870
1
Devices with IEC 60870-5-103 interfaces can be connected
Substation
to SICAM in parallel via the RS485 bus or radially via optical control system
fiber. Via this interface, the system is open for connection of
devices from other manufacturers.
Due to the standardized interfaces, SIPROTEC devices can 2
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 wir-
ing with the RS485 bus, as well as interference-free optical
SIP-0003a-en.ai
connection to the master can be implemented at low cost. 3
IEC 61850 SIPROTEC 4 SIPROTEC 4 SIPROTEC Compact
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
Fig. 2/19 IEC 60870-5-103: Radial fiber-optic connection
4
PC with SICAM. The interface is standardized, thus enabling
the direct connection of devices from other manufacturers to
the Ethernet bus. Option: Control
DIGSI SICAM center
With IEC 61850, the devices can also be installed in systems
of other manufacturers.
PAS
5
switch
SIP-0004a-en.ai
7
Fig. 2/20 Bus structure for station bus with Ethernet and IEC 61850, 8
fiber-optic ring
10
LSP3.01-0021.eps
Fig. 2/21 Optical Ethernet communication module for IEC 61850

Communication
System solution (continued)

1 Operating and Telecontrol interface to
Time syncronization
monitoring system control centers
(e.g. IEC60870-5-104) DCF77, GPS
Max. 12
2 Substation
controller
e.g. temperature sensor
RJ45
Station bus
RTD box
3 1) 1) 1) 1)
4 DIGSI
LSA4868b-en.ai
7SK80 7SK80 7SK80 7SK80 DIGSI 4
Telecontrol
DIGSI via modem
5 DIGSI 4
(Local for IBS)
Fig. 2/22 System solution/communication
2_23_Visio-SICAM-IO-Unit-02-20120731-us.pdf
Port A Y cable
To substation Max. 12 RJ45 cable 7KE6000-8GD00-0BA2
controller temperature sensor
RJ45 cable
Y cable
7 RTD box
7SK80 only
7KE6000-8GD00-0BA2
RJ45 cable RJ45 cable
Switch Switch
RTD-Unit
8 7XV5673
SICAM I/O Unit
7XV5673
SICAM I/O Unit
7XV5662
Port B Port A Fig. 2/24

Connection of 2 SICAM I/O Units and 1 RTD-box using Y cable
RJ45 1) (maximum 2 SICAM I/O-Units lockable)
9 s
2_24_Visio-SICAM-IO-Unit-01-20120731-us.pdf
Port A Y cable
RJ45 cable 7KE6000-8GD00-0BA2
7SK80
LSA4825b-en.ai
RJ45 cable
DIGSI
7SJ80 or
DIGSI 4 7SK80
(Local for IBS)
10 Fig. 2/23 Connection of an RTD box to 7SK80

Switch Switch
using Ethernet interface

7XV5673 7XV5673
1) On SIPROTEC 7SK80, the RJ45 interface at port A Fig. 2/25 SICAM I/O Unit SICAM I/O Unit
can be used for connection of a thermo-box. On Connection of 2 SICAM I/O Units on port A using Y cable
SIPROTEC 7SD80, port A is reserved for the optical
(maximum 2 SICAM I/O-Units lockable)
interface.

Line Differential
Protection 7SD80
SIPROTEC Compact
Page
1
Description 3/3
Function overview 3/4
2 Applications 3/5
Application sheets 3/6
Application examples 3/9
3 Connection diagrams 3/14
Connection examples 3/20
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 1
overhead lines up to 24km for all kind of starpoint configura-
tions.
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 2
out directly without external equipment over copper wires,
optical fibers or both in redundancy. The wide scope of non
3_2_LSP3.01-0008.eps
directional and directional functions can be applied miscella-
neously 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
3
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
4
Fig. 3/1 SIPROTEC 7SD80 front view
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 com-
missioning times.
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 6
both options communication redundancy is realised. Com-
munication 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 7
7SD80 devices.
Highlights
• Pluggable current and voltage terminals
• Binary input thresholds settable using DIGSI (3 stages) Fig. 3/2 SIPROTEC 7SD80 rear view
8
• Secondary current transformer values (1 A / 5 A) settable
using DIGSI
SIPROTEC 7SD80-specific features
• 9 programmable function keys
• 6-line display
• Short commissioning times by an easy parameterization
and integrated commissioning help for protection and
9
• Buffer battery exchangeable from the front communication
• USB front port • Integrated interfaces for exchanging differential protec-
• 2 additional communication ports tion data (fiber-optic up to 24 km / 15 miles and/or two-
• Integrated switch for low-cost and redundant optical wire copper cables up to 20 km / 12 miles)
Ethernet rings • Application for differential protection
• Ethernet redundancy protocol RSTP for highest availability • Integrated monitoring function of the protection inter-
• Relay-to-relay communication through Ethernet with face, both in the commissioning phase and in running
IEC 61850 GOOSE operation 10
• Millisecond-accurate time synchronization through • Integrated non-directional and directional time-
Ethernet with SNTP. overcurrent protection
• Transmission of a circuit-breaker intertripping signal and
16 further binary signals to the opposite end.

Function overview
Protection functions IEC ANSI No. Comment

Differential protection, line ∆I 87L
1 3I0 differential protection ∆3I0 87N L
Ground-fault differential protection for systems with resonant or isolated neutral ∆IEE 87Ns L Optional
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)
2 Inverse time-overcurrent protection (phase) IP 51
Inverse time-overcurrent protection (ground) IEP 51N
Inrush current detection
Circuit-breaker failure protection LSVS 50BF
Trip-circuit supervision AKU 74TC
3 Lockout 86
Circuit-breaker intertripping scheme 85 DT
External trip initiation
Undervoltage/overvoltage protection V<, V> 27/59 Optional
4 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 Optional
5 Flexible protection functions for current, voltage, power, cosj, frequency Flex Funk Partly optional
2
Thermal overload protection I t 49
Control functions
Table 3/1 Function overview

6
Control functions / programmable logic Communication interface
• Commands (e.g. for the control of circuit-breakers, discon- • System interface
nect switches, grounding switches, etc.) through: –– IEC 61850 Edition 1 and 2
7 –– keyboard –– IEC 60870-5-103
–– binary inputs –– MODBUS RTU
–– DIGSI 4 –– DNP 3.0
–– communication interface –– PROFIBUS-DP
8 • User-defined PLC logic with CFC (e.g. interlocking). –– Ethernet redundancy protocol RSTP
• Service interface
Monitoring functions
–– USB front interface for DIGSI 4
• Operational measured values V, I, f
–– RS232/RS485 (instead of the system interface)
9 • Energy metering values Wp, Wq
• Protection interface
• Circuit-breaker wear monitoring
–– Fiber-optic connection and/or
• Minimum and maximum values
–– Two-wire connection.
• Trip circuit supervision
• Fast measuring voltage failure “fuse-failure-monitor” Hardware
• 8 oscillographic fault records. • 4 current transformers
• 0/3 voltage transformers
10 • 3/5/7 binary inputs (thresholds configurable using

software)
• 5/8 binary outputs (2 changeover)
• 1 life contact
• Pluggable current and voltage terminals.

Applications
The SIPROTEC 7SD80 is a numerical line differential Operational measured values

protection relay, which in addition to its main function,
the selective protection of overhead lines and cables, also
Extensive measured values (e.g. I, V), metered values
(e.g.Wp,Wq) and limit values (e.g. for voltage, frequency) 1
covers control and monitoring tasks.
provide improved system management as well as simplifi-
Line protection cation by the commissioning
As for the operational measured values, a special focus was
SIPROTEC 7SD80 devices are suitable as selective line protec-
tion for application in high-voltage and medium-voltage
placed on the measured values critical for differential pro-
tection. So, the attenuation values and the signal-to-noise
2
systems of all types of neutral designs (solid, low-resistance
ratio of the communication connection, for example, are
or high-resistance earthed, isolated or compensated).
acquired and indicated in addition to the measurement of
Apart from the main protection function, the line differen- the quality of the telegram exchange per time unit.
tial protection, SIPROTEC 7SD80 offers a lot of additional
Particular attention was paid to making the commission-
protection functions. These can be used in parallel as a
backup protection function, or as an emergency function if
ing of the differential protection easier and safer. In this
context, the amplitude and angle of the currents and of 3
the main protection function fails, and they complement the
the voltages, if applicable, are displayed additionally with
range of functions of 7SD80 for application in transmission
reference to the local measuring variable. In this way, a pos-
lines.
sible incorrect connection (polarity reversal) of the current
Control transformers can be detected and eliminated early enough.
4
The integrated control function permits control of discon- Operational indication
nect devices, grounding switches or circuit-breakers through
Monitoring of operation is ensured and documented by stor-
the integrated operator panel, binary inputs, DIGSI 4 or the
age of event logs, trip logs, fault records and statistics.
control or automation system (e.g. SICAM)
5
Programmable logic
The integrated logic characteristics (CFC) allow the user to
add own functions for automation of switchgear (e.g. inter-
locking) or switching sequence. The user can also generate
user-defined messages. This functionality can form the base
6
to create extremely flexible transfer schemes.
7
Busbar
Control/Remote Control
Commands/Feedbacks
Measurement and metered value
PDI-FO
Supervision functions Protection Data Interface
(PDI) 8
Threshold value
opt. Budget V-Trans.monitor. BERT fiber-optic interface
52 Mean value I, V, Watt Rec. Power
I/V-Symmetry Rec.Power (4 km MMF or 20 km SMF)
Energy value Vars, p, f PDI-Cu S/N-Ratio
74TC 86 S/R-Ratio Fast Sum. I
min/max-memory AND / OR
Rec. Power
2-Wire-Copper interface
(SH-DSL to approx. 20 km) 9
87L 87N L 87NsL 67 67N 79 85 DT DT binTrans
directional emergency- and/or

Main protection function backup protection function
3_3_Bild-001-us.pdf
Inrush 50TD 51 50NTD 51N 50BF
non-directional emergency- and/or backup protection

FlexFunk 49 81U/O 27/59
10
Current Monitoring function Additional protection functions
Fig. 3/3 Function diagram

Application sheets
Protection functions Each of the overcurrent protection stages can be set as

emergency or backup protection independently of each
1 Differential protection (ANSI 87L, 87N L, 87Ns L)
The differential protection for SIPROTEC 7SD80 consists of
other. This enables the integration of the SIPROTEC 7SD80
in a simple busbar protection concept by means of reverse
two separately operating differential protection algorithms: interlocking. When voltage transformers are connected, a
directional time-overcurrent protection emergency function
• Phase comparison protection (PCP)
can be activated if the protection interface communication
2
• Earth-fault differential protection (EFD). fails.
The phase comparison protection, PCP, offers a safe and Available inverse-time characteristics
robust short-circuit protection for all types of neutral treat-
ment. Of course, this is also valid for application in systems Characteristics acc. to IEC 60255-3 ANSI / IEEE
with isolated or resonant-earthed neutral. Adaptation of Inverse ● ●
the phase comparison protection according to the neutral ●

Short inverse
3
treatment is done by setting parameters via DIGSI.
Long inverse ● ●
The earth-fault differential protection, EFD, operates with
Moderately inverse ●
two different algorithms, depending on the neutral treat-
● ●
ment in the power system to be protected. Very inverse
Extremely inverse ● ●
For application in solidly, low-resistance or high-resistance
4 earthed systems, the EFD analyzes the measured
zero-sequence current. The fundamental wave of the
Table 3/2 Available inverse-time characteristics
Inrush restraint
zero-sequence current is determined by filtering. The filtered
zero-sequence currents of the local side and the opposite When the second harmonic is detected while energizing a
side are added and provide the zero-sequence differential transformer inside or outside of the protection zone, pickup
5 current. The adaptive stabilizing facilitates the parameteriza-
tion and assured stability and selectivity.
of the differential protection stages or the overcurrent
protection stages can be suppressed.
For application in power systems with isolated or resonant-
Breaker failure protection (ANSI 50BF)
earthed neutrals, the connection of voltages – at least
of the zero-sequence voltage – and the use of a sensitive If a faulted portion of the electrical circuit is not disconnected
6 earth-current transformer is required. From the zero-
sequence current and the voltage, the apparent power of
when a trip command is issued to a circuit-breaker, another
trip command can be initiated using the breaker failure pro-
the zero-sequence system is calculated, and compared with tection which trips the circuit-breaker of an upstream feeder.
the opposite end. Depending on the direction of the power Breaker failure is detected if, after a trip command is issued
flow, an internal or external earth fault is detected. This is
7 only indicated, and can be shut down immediately or with a
set delay.
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.
Circuit-breaker intertripping (ANSI 85 DT)
The 7SD80 devices have an integrated circuit-breaker inter- External trip initiation
8 tripping function for tripping the circuit-breaker at the oppo- Through a binary input, an external protection device
site end. The circuit-breaker intertripping can be activated or monitoring equipment can be coupled into the signal
directly by the differential protection functions, but also processing of the SIPROTEC 7SD80 to trip the local circuit-
through binary signals of any other external or internal pro- breaker.
tection function. The circuit-breaker intertripping can be
9 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 instru-
ment 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 characteris-
tics can be added.

Application sheets
Trip circuit supervision (ANSI 74TC) Undervoltage protection (ANSI 27)

The circuit-breaker coil and its feed lines are monitored via The two-element undervoltage protection provides protec-
2 binary inputs. If the trip circuit is interrupted, and alarm tion against dangerous voltage drops (especially for electric 1
indication is generated. machines). Applications include the isolation of generators
or motors from the network to avoid undesired operating
Flexible protection functions conditions and a possible loss of stability. Proper operating
conditions of electrical machines are best evaluated with the
2
SIPROTEC 7SD80 enables the user to easily add up to 20
additional protective functions. Parameter definitions are positive-sequence quantities. The protection function is ac-
used to link standard protection logic with any chosen tive over a wide frequency range (± 10 % rated frequency).
characteristic quantity (measured or calculated quantity). Even when falling below this frequency range the function
The standard logic consists of the usual protection elements continues to work, however, with decreased accuracy. The
such as the pickup set point, the set delay time, the TRIP function can operate either with phase-to-phase, phase-
command, a block function, etc. The mode of operation for to-ground or positive phase-sequence voltage, and can be
current, voltage, power and power factor quantities can be
three-phase or phase-selective. Almost all quantities can be
monitored with a current criterion. Three-phase and single-
phase connections are possible.
3
operated with ascending or descending pickup stages (e.g.
Frequency protection (ANSI 81O/U)
under and over voltage). All stages operate with protection
priority or speed. Frequency protection can be used for overfrequency and
underfrequency protection. Electric machines and parts
of the system are protected from unwanted frequency
4
deviations. Unwanted frequency changes in the network
Measured-value Parameter Standard protection logic
processing (simplified diagram)
can be detected and the load can be removed at a specified
I measured
Current
Pickup frequency setting. Frequency protection can be used over
5
4
V measured Time
3I0, I1, I2 TRIP a wide frequency range (± 10 Hz rated frequency). There
3V0, V1, V2 t command
are four elements (individually set as overfrequency,
Visio-flexProFunc-de.pdf
Voltage
3 P,Q Threshold
cos φ
Function 1
underfrequency or OFF) and each element can be delayed
f
df/dt
Function 2 separately. Blocking of the frequency protection can be
Function 20
dV/dt performed by activating a binary input or by using an
undervoltage element. 6
Fig. 3/4 Flexible protection functions
Customized functions (ANSI 32, 51V, 55 etc.)
Additional functions can be implemented using CFC or
Lockout (ANSI 86) flexible protection functions. Typical functions include
All binary output statuses can be memorized. The LED reset

reverse power, voltage controlled overcurrent, phase angle 7
detection, and zero-sequence voltage detection.
key is used to reset the lockout state. The lockout state is
also stored in the event of supply voltage failure. Reclosure Fast current monitoring
can only occur after the lockout state is reset. and further monitoring functions
Thermal overload protection (ANSI 49) SIPROTEC 7SD80 incorporates comprehensive monitoring 8
func-tions for hardware and software. Monitoring comprises
To protect cables, an overload protection function with an the measuring circuits, the analog-digital conversion, the
integrated warning/alarm element for temperature and protection data communication connection the internal
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
supply voltages, the memories and the software sequence
(watchdog). 9
energy losses. The calculated temperature is constantly
adjusted according to the calculated losses. The function
considers loading history and fluctuations in load.
Overvoltage protection (ANSI 59)

The two-element overvoltage protection detects unwanted
network and machine overvoltage conditions. The function
can operate either with phase-to-phase, phase-to-ground,
positive phase-sequence or negative phase-sequence
10
voltage. Three-phase and single-phase connections are
possible.

Application sheets
Local measured values Measured values of protection data communication

The r.m.s. values are calculated from the acquired current Extensive measured values serve for the monitoring of
1 and voltage along with the power factor as well as cos j, the quality and the availability of the used protection data
frequency, active and reactive power. The following func- communication connections. For the fiber-optic interface,
tions are available for measured value processing: the following measured values are available:
• Currents IL1, IL2, IL3, IN, IEE • Sending and receiving power of the optical communica-
2 • Voltages VL1, VL2, VL3, V12, V23, V31

• Symmetrical components I1, I2, 3I0; V1, V2, 3V0
tion module
• Optical damping of the fiber-optic cable
• Power Watts, Vars, VA/P, Q, S (P, Q: total and phase • Telegrams sent per second, minute and hour
selective) • Sum of correct and incorrect telegrams received per
• Power factor cos j (total and phase selective) second, minute and hour
• Frequency • Availability of the protection interface.
3 • Energy ± kWh, ± kVarh, forward and reverse power flow For the two-wire interface, the following measured values
are available:
• Operating hours counter
• Damping of the copper cable
• Mean operating temperature of the overload function
• Signal-to-noise ratio of the signal received
• Limit value monitoring.
4 Limit values can be monitored using programmable logic
• Telegrams sent per second, minute and hour
in the CFC. Commands can be derived from this limit value • Sum of correct and incorrect telegrams received per
indication. With each measured value a limit value is second, minute and hour
possible. • Availability of the protection interface.
5 Zero suppression: Metered values

In a certain range of very low measured values, the value is For internal metering, the unit can calculate an energy me-
set to zero to suppress interference. tered value from the measured current and voltage values. If
an external meter with a metering pulse output is available,
Measured values of the opposite end
6 Every two seconds, the currents and voltages of the other
the SIPROTEC 7SD80 can obtain and process metering pulses
through an indication input. The metered values can be dis-
end of the line are transmitted through the communication played and passed on to a control center as an accumulated
connection, and indicated in relation to the locally measured value with reset. A distinction is made between forward,
currents and voltages. The following measured values are reverse, active and reactive energy.
7 available:
• Amplitude of currents IL1, IL2, IL3
• Phase angle of currents jIL1, jIL2, jIL3
• Amplitude of voltages VL1, VL2, VL3
8 • Phase angle of voltages jVL1, jVL2, jVL3.
10

Application examples
Radial feeder
The protection of a radial feeder with Infeed Infeed
several substations via overcurrent- 1
time protection leads to comparably
high shutdown times at the point 52 I> 1.2 IN; TI> = 1.2 s 52
of infeed due to the necessary
7SJ80 7SD80
time grading. The stipulated fault
clearance time may therefore not be
I> ΔI
2
attainable.
Protection Data Interface
Here, using the line differential pro- Station A
tection SIPROTEC 7SD80 is a simple
7SD80
remedy. This relay clears faults ΔI
between the substations selectively
and instantaneously, thus reducing
the maximum fault clearance time of
Station A
Load
Station A
Load
3
the radial feeder.
52 I> 1.2 IN; TI> = 0.9 s 52 I> 1.2 IN; TI> = 0.9 s
In the example shown, this is repre-
sented generally for the line between 7SJ80 7SJ80
the infeed and substation A.
I> I>
4
Station B Station B
Load Load
52 I> 1.2 IN; TI> = 0.6 s 52 I> 1.2 IN; TI> = 0.6 s
5
7SJ80 7SJ80
I> I>
Station C
Load
Station C
Load 6
52 I> 1.2 IN; TI> = 0.3 s 52 I> 1.2 IN; TI> = 0.3 s
7SJ80 7SJ80
I> I>
7
Station D Station D
Load Load
52 I> 1.2 IN ; TI > = 0 s 52 I> 1. 2 IN ; TI > = 0 s

8
7SJ80 7SJ80
3_5_Bild-002-us.pdf
I> I>
Load Load
9
3_5_7SD80_Protection concept.tif
max. fault clearance time from power utility

Tripping time for overcurrent protection only
Tripping time when using differential protection
10
Fig. 3/5 Protection concept to reduce the shutdown times at the
point of infeed of a radial feeder
Trafo 2 Wickl mit Erdung

Applications examples
Parallel feeder
Parallel feeders with bidirectional
1 power flow can be ideally protected Infeed
with the line differential protection

SIPROTEC 7SD80.
52 52
As a difference to the alternative
2 concept of the direction comparison 7SD80 7SD80

ΔI ΔI
protection, SIPROTEC 7SD80 does not
require voltage transformers.
Protection Data Interface Protection Data Interface
The communication connection
required in each case only leads to
7SD80 7SD80
instantaneous, strictly selective trip- ΔI ΔI
ping when the differential protection
3 is used Station A
In addition, the shorter fault clear-
ance time prevents damage to the 52 52
3_6_Bild-003-us.pdf
generators at the opposite end.
7SJ80 7SJ80
4 I> I>
5 Fig. 3/6 Protection of parallel feeders via SIPROTEC 7SD80
10

Ring feeder
The line differential protection
SIPROTEC 7SD80 is ideally suited to Infeed Infeed
1
protect ring feeders. Faults on the
connection cables/lines of the ring
52 52 52
are cleared strictly selectively and 7SD80 7SD80
instantaneously. For this purpose,
connection of the SIPROTEC 7SD80
ΔI >Z >Z ΔI
2
devices to a current transformer is
Protection Data Interface Ring feeder Protection Data Interface
sufficient. For the main protection
function of the SIPROTEC 7SD80, Station A Station B
ΔI
voltage transformers are not neces- ΔI
sary. Even intermediate infeeds in 7SD80 7SD80

the substations of the ring are
completely covered by this protection
52 52
3
concept.
52 52 52 52
Common alternative protection con- 7SD80 7SJ80 7SJ80 7SD80
cepts are mostly based on the use of
4
ΔI I> I> ΔI
directional time-overcurrent protec-
tion, which on the other hand also Load Load
requires voltage transformers in
the substations. An inverse grading Station C Station D
ΔI
of these directional definite time- ΔI
overcurrent protection devices, how-

ever, leads to long fault clearance 52
7SD80
52
7SD80 5
times. The use of the definite time-
overcurrent relays as direction com-
52 52 52 52
parison protection requires – like
3_7_Bild-004-us.pdf
7SD80 7SJ80 7SJ80 7SD80
the differential protection – a com-
munication connection between the
ΔI I> I> ΔI 6
protection devices at the ends of the
Load Load
corresponding ring segment, but this
does not reach the fault clearance
time of the differential protection.
Ring feeder
7
The definite time-overcurrent pro-
tection integrated in SIPROTEC 7SD80
includes three stages, two thereof Fig. 3/7 Protection concept for ring feeders via SIPROTEC 7SD80
can also be used as directional
definite time-overcurrent protection 8
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 9
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. Trafo 2 Wickl mit Erdung
10

Selection and ordering data
Product description Order No. Short code

12345 6 7 8 9 10 11 12 13 14 15 16 17 18 19
1 7SD80 - - +
Housing 1/6 19”, binary inputs and outputs, 1 life contact

4 x I, 3 BI, 5 BO (Incl. 2 changeover / Form C), prot. data interface FO for
2 mono- (24 km) and multimode (4 km), LC-duplex connector

4 x I, 7 BI, 8 BO (Incl. 2 changeover / Form C), prot. data interface FO for
1
mono- (24 km) and multimode (4 km), LC-duplex connector 2

4 x I, 5 BI, 8 BO (Incl. 2 changeover / Form C), prot. data interface, 2 wires copper, twisted 3) 3 see
4 x I, 3 x V, 3 BI, 5 BO (Incl. 2 changeover / Form C), prot. data interface FO for next
mono- (24 km) and multimode (4 km), LC-duplex connector 5 page
4 x I, 3 x V, 7 BI, 8 BO (Incl. 2 changeover / Form C), prot. data interface FO for
3 mono- (24 km) and multimode (4 km), LC-duplex connector

4 x I, 3 x V, 5 BI, 8 BO (Incl. 2 changeover/Form C), prot. data interface, 2 wires copper twisted 3)
6
7
Measuring inputs, default settings I

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
4 Rated auxiliary voltage
DC 24 V to 48 V 1
DC 60 V to 250 V; AC 115 V; AC 230 V 5
Unit version
5 Surface mounting housing, screw-type terminal B
Flush mounting housing, screw-type terminal E
Region-specific default- and language settings

Region DE, IEC, language German (Language selectable), standard face plate A
6 Region World, IEC/ANSI, language English (Language selectable), standard face plate
Region US, ANSI, language US-English (Language selectable), US face plate
B
C
Port B (at bottom of device)

No port 0
IEC 60870-5-103 or DIGSI 4/modem or time sync. port, electrical RS232
7
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
PROFIBUS DP slave, electrical RS485 9 L 0 A
8 PROFIBUS DP slave, optical, double ring, ST connector

MODBUS, electrical RS485
9
9
L 0 B
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
9 IEC 60870-5-103, redundant, electrical RS485, RJ45 connector

IEC 61850, 100 Mbit Ethernet, 2 electrical ports, RJ45 connector
9
9
L 0 P
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) 7
Measuring / fault recording
10 With fault recorder

With fault recorder, average values, min/max values
1
3
3) B y using 2-wire-protection interface a external isolating

1) T he FO interface is equipped, transformer should be used
if MLFB position 6 = 1, 2, 5 or 6 – PCM-transformer 6 kV orderno. C53207-A406-D195-1
2) Only if MLFB position 6 = 3 or 7 – 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. Short code

12345 6 7 8 9 10 11 12 13 14 15 16 17 18 19
7SD80 - - +
1
1)
Medium voltage differential protection device F A
87L / 87N L Line differential protection
(phase comparison and 3IO differential protection 1))
50 TD / 51
Inrush-current detection
Definite/inverse time-overcurrent protection phase I>, I>>, I>>>, Ip
2
50N TD / 51N Definite/inverse time-overcurrent protection ground IE>, IE>>, IE>>>, IEp
49 Thermal overload protection
74TC Trip circuit supervision
50BF Circuit-breaker failure protection
86 Lockout
85 DT Circuit-breaker intertripping function (trip of the remote circuit-
breaker)
External trip initiation
3
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) 4
27 / 59 Under-/Overvoltage protection 2) V<, V>
81 U / O Under-/Overfrequency protection 2) f<, f>
Basic version included F B
67 Directional definite/inverse time-overcurrent protection, phase 3)
67N
∠(V,I) I>, I>>, Ip
Directional definite/inverse time-overcurrent protection ground 3)
5
∠(V,I) IE>, IE>>, IEp
Basic version included F C
87Ns L Ground-fault differential protection for isolated/
resonance-earthed networks 3) 4)
Basic version included F E
6
3)
67 Directional definite/inverse time-overcurrent protection, phase
∠(V,I) I>, I>>, Ip
67N Directional definite/inverse time-overcurrent protection, ground 3)
∠(V,I) IE>, IE>>, IEp
87Ns L 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
79
With automatic reclosure function (AR)
Transmission of 16 binary signals via the protection data interface
2
3
8
and with automatic reclosure function (AR)
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
F1 IA BO1 C11
C10
F2 C9
F3 IB
BO2 C14
2 F4
F5 IC
C12
C13
F6
BO3 E1
F7 I N, INS
E2
F8
BO4 E3
E4
3 BO5 E5
E6
C3
4 C4
BI1
C5 BI2
C6
C7 BI3 Life Contact E10
C8
5
E7
E8
= + C1
Power Supply (~)
=
- C2
6 Port B
B
e.g. System interface
Port A
A
7
3_8_Visio-kl-uebers-7sd80-1-100801-us.pdf
FO-Protection Data Interface

Contacts, Ceramic, 2.2 nF,
Interference Suppression
Capacitors at the Relay
USB-DIGSI-Interface
8 Grounding on the case

250 V
Fig. 3/8 Line differential protection SIPROTEC 7SD801
10

Connection diagrams
Surface / flush-mounting housing

1
F1 IA BO1 C1 1
F2 C10
C9
F3 IB
BO2 C1 4
F4
F5 IC
C12
C13
2
F6
BO3 E1
F7 I N, INS
E2
F8
BO4 E3
E4
BO5 E5
E6
3
BO6 D9
D10
BO7 D11
C3
C4
BI1
BO8
D12
D13
4
C5 BI2 D14
C6
C8
5
E7
E8
D1 BI4
D2 = +
(~) C1
Power Supply
D3 BI5
=
- C2
D4
D5
D6
BI6
Port B
6
B
D7 BI7 e.g. System interface
D8
Port A
A
7

USB-DIGSI-Interface
Grounding on the case 8

250 V
10

Connection diagrams
F1 IA BO1 C1 1
F2 C10
C9
F3 IB
BO2 C1 4
2 F4
F5 IC
C12
C13
F6
BO3 E1
F7 I N, INS
E2
F8
BO4 E3
E4
3 BO5 E5
E6
BO6 D9
D10
BO7 D11
C3
4 C4
BI1
BO8
D12
D13
C5 BI2 D14
C6
C7 BI3
C8 Life Contact E10
5 E7
E8
D1
Cu-Protection Data Interface
D2 = +
(~) C1
Power Supply
D5 BI4
=
- C2
D7
6 D6 BI5 Port B
D8 B
Port A
A
7 FO-Protection Data Interface
USB-DIGSI-Interface

250 V
9 The fiber-optic interface at port A is only available in connection with position 12 = 7
10

Connection diagrams

1
F1 IA BO1 C1 1
F2 C10
C9
F3 IB
BO2 C1 4
F4
F5 IC
C12
C13
2
F6
BO3 E1
F7 I N, INS
E2
F8
BO4 E3
E9 Q2 VA E4
E11
E12
VB BO5 E5
E6
3
E13 VC
E14
C3
C4
BI1
4
C5 BI2
C6
C7 BI3
C8 Life Contact E10
E7
E8 5
= + C1
Power Supply (~)
=
- C2
Port B
6
B
Port A
A
7
USB-DIGSI-Interface

250 V
10

Connection diagrams
F1 IA BO1 C1 1
F2 C10
C9
F3 IB
BO2 C1 4
2 F4
F5 IC
C12
C13
F6
BO3 E1
F7 I N, INS
E2
F8
BO4 E3
E9 Q2 VA E4
3 E11
E12
VB BO5 E5
E6
E13 VC BO6 D9
E14 D10
BO7 D11
C3
4 C4
BI1
BO8
D12
D13
C5 BI2 D14
C6
C8
5
E7
E8
D1 BI4
D2 = +
(~) C1
Power Supply
D3 BI5
=
- C2
D4
6 D5
D6
BI6
Port B
B
D7 BI7 e.g. System interface
D8
Port A
3_12 Visio-kl-uebers-7sd80-2-100801-us.pdf
A
7 FO-Protection Data Interface
USB-DIGSI-Interface

250 V
10

Connection diagrams

1
F1 IA BO1 C1 1
F2 C10
C9
F3 IB
BO2 C1 4
F4
F5 IC
C12
C13
2
F6
BO3 E1
F7 I N, INS
E2
F8
BO4 E3
E9 Q2 VA E4
E11
E12
VB BO5 E5
E6
3
E13 VC BO6 D9
E14 D10
BO7 D11
C3
C4
BI1
BO8
D12
D13
4
C5 BI2 D14
C6
C7 BI3
C8 Life Contact E10
E7
E8 5
D1
Cu-Protection Data Interface
D2 = +
(~) C1
Power Supply
D5 BI4
=
- C2
D7
D6 BI5 Port B
6
D8 B
Port A
A
7
USB-DIGSI-Interface

250 V

The fiber-optic interface at port A is only available in connection with position 12 = 7
9
10

Connection examples
Current transformer connection
1 52 52 52
Surface-/Flush Mounting Housing
F1 IA F2
IB
3_14_SIP C-0007-us.pdf
F3 F4
2 P2 S2
F5 IC F6
IN
P1 S1 F7 F8
A B C SIPROTEC
3 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
F1 IA F2
5 IB
P2 S2
F3 F4
F5 IC F6
P1 S1
IN
6 A B C
F7
SIPROTEC
F8
Fig. 3/15 Current transformer connections on three current transformers and

neutral current (earth current) (Holmgreen circuit); normal circuit
7 suitable for all solidly and impedance earthed systems (neutral towards
busbar)
8 52 52 52
IA
F1 F2
IB
F3 F4
9 P2 S2
F5
IC
F6
IN
P1 S1 F8 F7
SIPROTEC
A B C
P2 S2
10
P1 S1
Fig. 3/16 Current transformer connections on three current transformers –

earth current of additional summation current transformer, preferably
for resonant-earthed and isolated systems.

Connection examples
Voltage transformer connection
A
1
3_17_Visio-anschl-u1e-u2e-u3e-abgang-20070129-us.pdf
B
C
Surface-/Flush Mounting
Housing
52 52 52
A B
E9 VA
2
E11 VB
E12
a b VC
E13
E14
A B C
SIPROTEC
3
Fig. 3/17 Example for connection type “V1E, V2E, V3E”, feeder-side voltage connection
A
4
B
C
Housing
52 52 52
A B E9 VA
5
E11 VB
E12
da dn
E13
E14
VC
6
SIPROTEC
A B C
Fig. 3/18 Example for connection type “V0 connection”

7
10

10

Overcurrent
Protection 7SJ80
SIPROTEC Compact
Page
1
Description 4/3
2 Applications 4/5
Connection types 4/30
10

Description
Description
The SIPROTEC 7SJ80 relays can be used for line/feeder
protection of high and medium-voltage networks with 1
grounded, low-resistance grounded, isolated or a com-
pensated neutral point. The relays have all the required
functions to be applied as a backup relay to a transformer
differential relay.
The SIPROTEC 7SJ80 features “flexible protection functions”. 2
Up to 20 additional protection functions can be created by
the user.
Therefore protection of change for frequency or reverse
power protection can be realized, for example.
The relay provides circuit-breaker control, further switching
3
LSP3.01-0022.eps
devices and automation functions. The integrated program-
mable 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 4
• Binary input thresholds settable using DIGSI (3 stages)
using DIGSI
Fig. 4/1 SIPROTEC 7SJ80 front view, housing
5
• 6-line display
• Buffer battery exchangeable from the front
• USB front port 6
• 2 additional communication ports
Ethernet rings
7
• Relay-to-relay communication through Ethernet with
IEC 61850 GOOSE
LSP3.01-0008.eps
• Millisecond-accurate time synchronization through

Ethernet with SNTP (over Port A or Port B) 8
• Number of binary inputs and inary outputs by connection
from up to two SICAM I/O-Units extendable.
Fig. 4/2 SIPROTEC 7SJ80 rear view
10

Function overview
Protection functions IEC ANSI No.

Definite and inverse time-overcurrent protection (phase/ground) I>, Ip, INp 50, 50N; 51, 51N
1 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
Overvoltage protection, zero-sequence system V E, V 0> 59N 1)
2 High-impedance restricted ground-fault protection 87N
Inrush restraint
Trip-ciruit supervision TCS 74TC
Undercurrent monitoring I<, P> 37
Overload protection J> 49
3 Undervoltage/overvoltage protection V<, V> 27/59
Overfrequency/underfrequency protection f<, f> 81O/U
Circuit-breaker failure protection CBFP 50BF
Undervoltage controlled reactive power protection Q>/V<
4 Intermittent ground fault protection Iie>
Directional intermittent ground fault protection Iie dir> 67Ns 1)
Voltage dependent inverse-time overcurrent protection 51V
Unbalanced-load protection I 2> 46
5 Phase-sequence-voltage supervision LA, LB, LC 47
Synchrocheck Sync 25
Automatic reclosing AR 79
Fault locator FL FL 1)
6 Lockout 86
Forward power supervision, reverse power protection P<>, Q<> 32 1)
Power factor cos j 55 1)
Rate-of-frequency-change protection df / dt 81R
7 Rate-of-voltage-change protection dV/dt 27R, 59R
Control functions/programmable logic Communication interfaces
8 • Commands for the ctrl. of CB, disconnect switches

(isolators/isolating switches)
• System/service interface
–– IEC 61850 Edition 1 and 2
• Control through keyboard, binary inputs, –– IEC 60870-5-103 and IEC 60870-5-104
DIGSI 4 or SCADA system –– PROFIBUS-DP
• User-defined PLC logic with CFC (e.g. interlocking). –– DNP 3.0
9 Monitoring functions
–– MODBUS RTU
–– DNP3 TCP
• Operational measured values V, I, f –– PROFINET
• Energy metering values Wp, Wq –– Ethernet redundancy protocols RSTP, PRP and HSR
• Circuit-breaker wear monitoring • Ethernet interface for DIGSI 4 and extension up to two
• Minimum and maximum values SICAM I/O-Units 7XV5673
• USB front interface for DIGSI 4.
• Trip circuit supervision (74TC)
• Fuse failure monitor Hardware
• 8 oscillographic fault records. • 4 current transformers
10 • 0/3 voltage transformers

• 3/7/11 binary inputs (thresholds configurable using
software)
• 5/8 binary outputs (2 changeover/Form C contacts)
1) Not available if function package “Q” (synchrocheck, ANSI 25) • 1 life contact
is selected.

Applications
The SIPROTEC 7SJ80 perform control and monitoring func- Operational indication
tions and therefore provide the user with a cost-effective
platform for power system management, that ensures
Event logs, trip logs, fault records and statistics documents
are stored in the relay to provide the user or operator with all 1
reliable supply of electrical power to the customers. The
the key data required to operate modern substations.
ergonomic design makes control easy from the relay front
panel. A large, easy-to-read display was a key design factor. Line protection
Control The SIPROTEC 7SJ80 units can be used for line protection
of high and medium-voltage networks with grounded, low-
2
The integrated control function permits control of discon-
resistance grounded, isolated or a compensated neutral point.
the integrated operator panel, binary inputs, DIGSI 4 or the Transformer protection
The relay provides all the functions for backup protection for
Programmable logic transformer differential protection. The inrush suppression
effectively prevents unwanted trips that can be caused by 3
inrush currents. The high-impedance restricted ground-fault
protection detects short-circuits and insulation faults on the
transformer.
to create extremely flexible transfer schemes. Backup protection 4
Operational measured value As a backup protection the SIPROTEC 7SJ80 devices are
universally applicable.
(e.g.Wp,Wq) and limit values (e.g. for voltage, frequency)
provide improved system management.
Switchgear cubicles for high/medium voltage
All units are designed specifically to meet the requirements
5
of high/medium-voltage applications. In general, no separate
measuring instruments (e.g., for current, voltage, frequency,
…) or additional control components are necessary.
6
Busbar
Local/remote control CFC logic Operational measured values
7
25 Synchrocheck
Commands/Feedbacks
Limits
V, f, P
52 AND Mean value I, V, P, Q,
cos φ, f Flexible protection functions
86 Lock out min/max-memory P<>, Q<> cosφ df/dt dV/dt
27R
32 55 81R
Operation Communication module 59R
1) 1)
Metered energy: as counting pulses
8
RS232/485/FO/ f<, f> V> V<
Ethernet 81U/O 59 27
IEC 60870-5-103/4 Fault recording Fault Locator
Esc Enter IEC 61850
7 8 9 PROFIBUS-DP Directional supplement
4
1
5
2
6
3
DNP 3.0
Fn 0 . MODBUS RTU
DNP3 TCP FL 47 Phase sequence
1)
PROFINET
... I>, I>> I-
TOC
IN>, IN>>,
IN-TOC 9
67 67N
1)
I>, I>>, IN>, IN>>, IN-TOC

I>>> I-TOC IN>>> I2> > SVS I<
InRush Intermitt. Additional Directional ground
50 51 50N 51N 46 49 51V
BLK ground fault 50BF 37 fault protection
INs>,
2_3_Visio-LSA4783b-us.pdf
INs>>
79 AR 67Ns-TOC VN>
67Ns 59N
50N 51N 87N 1) 1)
IN>, IN>>, IN-TOC REF
10
IN>>> Undervoltage
Contr.react.pow.protec.
AR Automatic reclosing I2> Unbalanced load protection

BF Breaker Failure Protection > Thermal overload protection
REF High-impedance ground fault differential protection I< Undercurrent monitoring
1) Not available if function package “Q” (synchrocheck, ANSI 25) is selected.

Application sheets
Protection functions Directional time-overcurrent protection (ANSI 67, 67N)

Directional phase and ground protection are separate
1 Overcurrent protection (ANSI 50, 50N, 51, 51N, 51V)
functions. They operate in parallel to the non-directional
This function is based on the phase selective measurement overcurrent elements. Their pickup values and delay times
of the three phase currents and the ground current (four can be set separately. Definite-time and inverse-time
transformers). Three definite time-overcurrent protection characteristics are
elements (DMT) are available both for the phase and the offered. The tripping characteristic can be rotated by ± 180
2 ground elements. The current threshold and the delay time degrees.
can be set in a wide range. By making use of the voltage memory, the directionality
Inverse time-overcurrent protection characteristics (IDMTL) can be determined reliably even for close-in (local) faults.
can also be selected and activated. The inverse-time func- If the primary switching device closes onto a fault and the
tion provides – as an option – voltage-restraint or voltage- voltage is too low to determine direction, the direction is
controlled operating modes determined using voltage from the memorized voltage. If no
3 Reset characteristics
voltages are stored in the memory, tripping will be accord-
ing to the set characteristic.
Time coordination with electromechanical relays are made For ground protection, users can choose whether the direc-
easy with the inclusion of the reset characteristics according tion is to be calculated using the zero-sequence or negative-
to ANSI C37.112 and IEC 60255-3 / BS 142 standards. When sequence system quantities (selectable). If the zero-sequence
4 using the reset characteristic (disk emulation), the reset pro- voltage tends to be very low due to the zero-sequence
cess is initiated after the fault current has disappeared. This impe-dance it will be better to use the negative-sequence
reset process corresponds to the reverse movement of the quantities.
Ferraris disk of an electromechanical relay (disk emulation).
5 Available inverse-time characteristics
Characteristics acc. to IEC 60255-3 ANSI / IEEE

Inverse ● ●
Short inverse ●
6 Long inverse ● ●
Very inverse ● ●
7 Table 4/2 Available inverse-time characteristics
Inrush restraint
If second harmonic content is detected during the energi-
8 zation of a transformer, the pickup of stages I>,Ip, I>dir

and Ip dir is blocked.
Fig. 4/4 Directional characteristics of the directional time-overcurrent
protection
Dynamic settings group switching

(Sensitive) directional ground-fault detection
In addition to the static parameter changeover, the pickup (ANSI 59N/64, 67Ns, 67N)
9 thresholds and the tripping times for the directional and
non-directional time-overcurrent protection functions can
For isolated-neutral and compensated networks, the
direction of power flow in the zero sequence is calculated
be changed over dynamically. As changeover criterion, the
from the zero-sequence current I0 and zero-sequence
circuit-breaker position, the prepared auto-reclosure, or a
voltage V0. For networks with an isolated neutral, the
binary input can be selected.
reactive current component is evaluated; for compensated
Directional comparison protection (cross-coupling) networks, the active current component or residual resistive
current is evaluated. For special network conditions, e.g.
It is used for selective instantaneous tripping of sections high-resistance grounded networks with ohmic-capacitive
fed from two sources, i.e. without the disadvantage of time ground-fault current or low-resistance grounded networks
delays of the set characteristic. The directional comparison
10 protection is suitable if the distances between the protection
with ohmic-inductive current, the tripping characteristics can
be rotated approximately
zones are not significant and pilot wires are available for ± 45 degrees (see Fig.4/5).
signal transmission. In addition to the directional compari-
Two modes of ground-fault direction detection can be
son protection, the directional coordinated time-overcurrent
implemented: tripping or “signalling only mode”.
protection is used for complete selective backup protection.

Application sheets
(Sensitive) directional ground-fault detection Negative-sequence system overcurrent protection (ANSI 46)
(ANSI 59N, 67Ns, 67N) (contin.)
By measuring current on the high side of the transformer,
It has the following functions: the two-element phase-balance current/negative-sequence 1
• TRIP via the displacement voltage VE protection detects high-resistance phase-to-phase faults
and phase-to-ground faults on the low side of a transformer
• Two instantaneous elements or one instantaneous plus
(e.g. Dy 5). This function provides backup protection for
one user-defined characteristic
high-resistance faults through the transformer.
• Each element can be set to forward, reverse or non-
directional Directional intermittent ground fault protection (ANSI 67Ns)
2
• The function can also be operated in the insensitive mode The directional intermittent ground fault protection has to
as an additional short-circuit protection. 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: 3
– 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
half-period up to several periods, depending on the power
system conditions and the fault characteristic. 4
– 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. 5
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 6
into relation with the zero-sequence voltage to determine the
direction.
Undervoltage-controlled reactive power protection

Fig. 4/5 Directional determination using cosine measurements for
compensated networks The undervoltage-controlled reactive power protection pro-
7
tects the system for mains decoupling purposes. To prevent a
(Sensitive) ground-fault detection voltage collapse in energy systems, the generating side, e.g.
(ANSI 50Ns, 51Ns / 50N, 51N) a generator, must be equipped with voltage and frequency
For high-resistance grounded networks, a sensitive input
protection devices. An undervoltage-controlled reactive
power protection is required at the supply system connection
8
transformer is connected to a phase-balance neutral current
point. It detects critical power system situations and ensures
transformer (also called core-balance CT). The function can
that the power generation facility is disconnected from the
also be operated in the normal mode as an additional short-
mains. Furthermore, it ensures that reconnection only takes
circuit protection for neutral or residual ground protection.
Intermittent ground fault protection

place under stable power system conditions. The associated
criteria can be parameterized.
9
Intermittent (re-igniting) faults are caused by poor cable in- Breaker failure protection (ANSI 50BF)
sulation or water ingress into cable joints. After some time,
If a faulted portion of the electrical circuit is not disconnected
the faults extinguish automatically or they develop into
permanent short circuits. During the intermitting, neutral
trip command can be initiated using the breaker failure pro-
point resistances in impedance grounded systems can suffer
tection which trips the circuit-breaker of an upstream feeder.
thermal overload.
Breaker failure is detected if, after a trip command is issued
The normal ground fault protection is not capable of reliably and the current keeps on flowing into the faulted circuit. It
detecting and clearing the sometimes very short current
pulses. The required selectivity for intermittent ground
is also possible to make use of the circuit-breaker position 10
contacts for indication as opposed to the current flowing
faults is achieved by summing up the times of the individual through the circuit-breaker.
pulses and tripping after a (programmable) summation time
has been reached. The pickup threshold Iie> evaluates RMS
values referred to 1 system period.

Application sheets
High-impedance restricted ground-fault protection • Initiation of the ARC is dependant on the trip command
(ANSI 87N) selected (e.g. I2>, I>>, Ip, Idir>)
1 The high-impedance measurement principle is a simple • The ARC function can be blocked by activating a binary input
and sensitive method to detect ground faults, especially on • The ARC can be initiated from external or by the PLC logic
transformers. It can also be used on motors, generators and (CFC)
reactors when they are operated on a grounded network. • The directional and non-directional elements can either
2
When applying the high-impedance measurement principle, be blocked or operated non-delayed depending on the
all current transformers in the protected area are connected auto-reclosure cycle
in parallel and operated through one common resistor of • If the ARC is not ready it is possible to perform a dynamic
relatively high R. The voltage is measured across this resistor setting change of the directional and non-directional
(see Fig. 4/6). overcurrent elements.
The voltage is measured by detecting the current through
the (external) resistor R at the sensitive current measure- Flexible protection functions
3 ment input IEE. The varistor V serves to limit the voltage in
the event of an internal fault.
The SIPROTEC 7SJ80 enables the user to easily add up to
20 additional protection functions. Parameter definitions
It limits the high instantaneous voltage spikes that can are used to link standard protection logic with any chosen
occur at current transformer saturation. At the same time, characteristic quantity (measured or calculated quantity).
this results to smooth the voltage without any noteworthy
4 reduction of the average value.
The standard logic consists of the usual protection elements
such as the pickup set point, the set delay time, the TRIP
If no faults have occurred and in the event of external or command, a block function, etc. The mode of operation for
through faults, the system is at equilibrium, and the voltage current, voltage, power and power factor quantities can be
through the resistor is approximately zero. In the event of three-phase or single-phase. Almost all quantities can be
5 internal faults, an imbalance occurs which leads to a voltage

and a current flowing through the resistor R.
under and overvoltage). All stages operate with protection
The same type of current transformers must be used and priority.
must at least offer a separate core for the high-impedance
restricted ground-fault protection. They must have the Measured-value Parameter Standard protection logic
4_7_Visio-flexProFunc-us.pdf
6
Current I measured
same transformation ratio and approximately an identical 4
V measured Time
Pickup
knee-point voltage. They should also have only minimal 3I0, I1, I2
t
TRIP
command
3V0, V1, V2
measuring errors. Voltage
3 P,Q Threshold
cos φ
Function 1
f
Function 2
df/dt
Function 20
dV/dt
7
Protection functions/stages available are based on the avail-

able measured analog quantities:
8 Function ANSI
I>, IE> 50, 50N
V<, V>, VE> 27, 59, 59N
9 3I0>, I1>, I2>, I2 / I1>, 3V0>, V1> <, V2 > < 50N, 46, 59N, 47
LSA4115-de.ai
P> <, Q> < 32

cos j 55
f>< 81O, 81U
Fig. 4/6 High-impedance restricted ground-fault protection df / dt > < 81R
dV/dt 27R/59R
Table 4/3 Available flexible protection functions
Automatic reclosing (ANSI 79)
Multiple re-close cycles can be set by the user and lockout For example, the following can be implemented:
10 will occur if a fault is present after the last re-close cycle.

The following functions are available:
• Reverse power protection (ANSI 32R)
• Rate-of-frequency-change protection (ANSI 81R)
• 3-pole ARC for all types of faults • Rate-of-voltage-change protection (ANSI 27R/59R).
• Separate settings for phase and ground faults
• Multiple ARC, one rapid auto-reclosure (RAR) and up to
nine delayed auto-reclosures (DAR)
Application sheets
Synchrocheck, synchronizing function (ANSI 25) Undervoltage protection (ANSI 27)

When closing a circuit-breaker, the units can check The two-element undervoltage protection provides protec-
whether two separate networks are synchronized. Voltage-, tion against dangerous voltage drops (especially for electric 1
frequency- and phase-angle-differences are checked to machines). Applications include the isolation of generators
determine whether synchronous conditions exist. or motors from the network to avoid undesired operating
conditions and a possible loss of stability. Proper operating
Trip circuit supervision (ANSI 74TC) conditions of electrical machines are best evaluated with
The circuit-breaker coil and its feed lines are monitored via the positive-sequence quantities. The protection function is 2
2 binary inputs. If the trip circuit is interrupted, and alarm active over a wide frequency range (45 to 55, 55 to 65 Hz).
indication is generated. Even when falling below this frequency range the function
continues to work, however, with decrease accuracy. The
Lockout (ANSI 86) function can operate either with phase-to-phase, phase-
to-ground or positive phase-sequence voltage, and can be
3
also stored in the event of supply voltage failure. Reclosure
can only occur after the lockout state is reset. Frequency protection (ANSI 81O/U)
Thermal overload protection (ANSI 49) Frequency protection can be used for overfrequency and
To protect cables and transformers, an overload protection
4
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
frequency setting. Frequency protection can be used over
IEC 60255-8), it considers the energy entering the equip-
ment and the energy losses. The calculated temperature is
a wide frequency range (40 to 60 (for 50 Hz), 50 to 70 (for
60 Hz)). There are four elements (individually set as over-
5
constantly adjusted according to the calculated losses. The
frequency, underfrequency or OFF) and each element can
function considers loading history and fluctuations in load.
be delayed separately. Blocking of the frequency protection
Settable dropout delay times can be performed by activating a binary input or by using an
If the relays are used in conjunction with electromechanical

undervoltage element. 6
relays, in networks with intermittent faults, the long dropout Fault locator (ANSI 21FL)
times of the electromechanical relay (several hundred mil-
The integrated fault locator calculates the fault impedance
liseconds) can lead to problems in terms of time coordination/
and the distance to fault. The results are displayed in Ω,
grading. Proper time coordination/grading is only possible if
the dropout or reset time is approximately the same. This is
kilometers (miles) and in percent of the line length. 7
why the parameter for dropout or reset times can be defined Customized functions (ANSI 51V, 55 etc.)
for certain functions, such as overcurrent protection, ground
short-circuit and phase-balance current protection. Additional functions, which are not time critical, can be im-
Undercurrent monitoring (ANSI 37)

plemented using the CFC measured values. Typical functions
include reverse power, voltage controlled overcurrent, phase 8
angle detection, and zero-sequence voltage detection.
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.

9
positive phase-sequence or negative phase-sequence volt-
age. Three-phase and single-phase connections are possible.
10

Application sheets
Further functions Circuit-breaker wear monitoring/

circuit-breaker remaining service life
1 Measured values
Methods for determining circuit-breaker contact wear or
The r.m.s. values are calculated from the acquired current the remaining service life of a circuit-breaker (CB) allow CB
and voltage along with the power factor, frequency, active maintenance intervals to be aligned to their actual degree of
and reactive power. The following functions are available for wear. The benefit lies in reduced maintenance costs.
measured value processing:
2 • Currents IL1, IL2, IL3, IN, IEE
There is no exact mathematical method to calculate the
wear or the remaining service life of a circuit-breaker that
• Voltages VL1, VL2, VL3, V12, V23, V31 takes arc-chamber’s physical conditions into account when
the CB opens.
• Symmetrical components I1, I2, 3I0; V1, V2, 3V0
This is why various methods of determining CB wear have
• Power Watts, Vars, VA/P, Q, S (P, Q: total and phase selec-
evolved which reflect the different operator philosophies.
tive)
To do justice to these, the relay offers several methods:
3 • Power factor cos j (total and phase selective)
• SI
• Frequency
• SIx, with x = 1..3
• Energy ± kWh, ± kVarh, forward and reverse power flow
• Si2t.
• Mean as well as minimum and maximum current and
4 voltage values
The devices also offer a new method for determining the
remaining service life:
• Two-point method
The CB manufacturers double-logarithmic switching cycle
• Limit value monitoring
diagram (see Fig. 4/8) and the breaking current at the time
5 Limit values can be monitored using programmable logic
in the CFC. Commands can be derived from this limit value
of contact opening serve as the basis for this method. After
CB opening, the two-point method calculates the remaining
indication.
number of possible switching cycles. Two points P1 and P2
• Zero suppression only have to be set on the device. These are specified in the
In a certain range of very low measured values, the value CB’s technical data.
6 is set to zero to suppress interference.
All of these methods are phase-selective and a limit value
Metered values can be set in order to obtain an alarm if the actual value falls
below or exceeds the limit value during determination of
For internal metering, the unit can calculate an energy me- the remaining service life.
tered value from the measured current and voltage values. If
7 an external meter with a metering pulse output is available,
the SIPROTEC 7SJ80 can obtain and process metering pulses
played and passed on to a control center as an accumulated
value with reset. A distinction is made between forward,
8 reverse, active and reactive energy.
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.
9 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 P1: Permissible number
through IEC 61850 GOOSE on Port B (System interface with of operating cycles
EN100 module). at rated normal
current
P2: Permissible number
of operating cycles
at rated short-
10 circuit 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 individu- 1
ally and the state of the binary outputs can be set individu-
ally. 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. 2
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 pur-
poses can be connected to a control and protection system.
Test operation 3
During commissioning, all indications with test tag can be
passed to a control system for test purposes.
10

Radial systems
1) Auto-reclosure Infeed
General hints:
1 The relay at the far end (D) from the
(ANSI 79) only with
overhead lines Transformer protection
infeed has the shortest tripping time. 2) Unbalanced load
Relays further upstream have to be protection (ANSI 46)
time-graded against downstream as backup protection
A 52
against asymmetrical
relays in steps of about 0.3 s.
2 faults Busbar
Further power supply B 52
I>t IN>t I2>t AR

51 51N 46 79
2) 1)
3 Busbar
C
* 52
I>t IN>t I2>t
4
51 51N 46
Load
Busbar
5 * D 52
4_9_LSA4839-en.pdf
I>t IN>t I2>t
51 51N 46
6 Load Load
Fig. 4/9 Protection concept with time-overcurrent protection
7
Earth-fault detection in isolated or
compensated systems
1) The sensitive current Infeed
8 In isolated or compensated systems,
an occurred earth fault can be
measurement of
the earth current
should be made by a
easily found by means of sensitive zero-sequence current
directional earth-fault detection. transformer
Busbar
9
52
I>> I>t
50 51
4_10_LSA4840a-en.pdf
7XR96 IN>t dir.
1) 67Ns
60/1
10 Load
Fig. 4/10 Protection concept for directional earth-fault detection

Ring-main cable
With the directional comparison
protection, 100% of the line can be Infeed Infeed
1
protected via instantaneous tripping 52
in case of infeed from two sources
(ring-main cable). 52 52
For lines with infeed from two sour-

ces, no selectivity can be achieved
I>t
51
IN>t
51N
υ>t
49
I2>t
46 Direct.Compar.Pickup
2
with a simple definite-time overcur-
rent protection. Therefore, the Overhead line Overhead line Protection as in
directional definite-time overcurrent or cable 1 or cable 2 the case of line
or cable 1
protection must be used. A non- I>t IN>t dir. I>t IN>t
directional definite-time overcurrent 67 67N 51 51N
protection is enough only in the

corresponding busbar feeders. The
3
52 52
grading is done from the other end
respectively. 52
Advantage: 100% protection of the
line via instantaneous 52 52
4
tripping, and easy
setting. 67 67N 51 51N
Direct.Compar.Pickup
Disadvantage: Tripping times increase I>t IN>t dir. I>t IN>t
towards the infeed. Overhead line

or cable 3
Overhead line
or cable 4
Protection as in
the case of line
or cable 3
5
I>t IN>t dir. I>t IN>t
67 67N 51 51N
52 52
6
52
52 52
7
I>t IN>t υ>t I2>t
51 51N 49 46
Load Load
Fig. 4/11 Protection concept of ring power systems
10

Busbar protection by overcurrent

relays with reverse interlocking
1 Applicable to distribution busbars Infeed
without substantial (< 0.25 x IN) Reverse interlocking

backfeed from the outgoing feeders.
I>>t0
2 50/50N 51/51N
52
t0 = 50 ms
Busbar
52 52 52
3 I>>
I>> I>t 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
In unstable power systems (e.g.
solitary systems, emergency
6 power supply in hospitals), it may
be necessary to isolate selected Busbar
consumers from the power system in
order to protect the overall system. V< f<
The overcurrent-time protection 52
7
27 81U
functions are effective only in the
case of a short-circuit.Overloading of I>, I>>, IN>,
the generator can be measured as a I>>> IN>> I>, Ip INTOC
50 50N 51 51N
frequency or voltage drop.
4_13_LSA2216b-en.pdf
8
> I2> Final trip
79M 49 46 86
Fig. 4/13 Line feeder with load shedding
10

Automatic reclosing
The Automatic reclosing function (AR)
has starting and blocking options. In the
52
Stage can
be blocked
Stage get slower executes the
than the fuse or reclosing for
1
opposite example, the application of the
lower protection the hole feeder
blocking of the high-current stages is devices graduated
represented according to the reclosing
cycles. The overcurrent protection is
2
ON
52 52
graded (stages I, Ip) according to the TRIP
grading plan. If an Automatic reclosing I>, I>>, I>>> I>t, I>>t, Ip
4_14_LSA2219d-en.pdf
function is installed in the incoming 50 51
supply of a feeder, first of all the complete IN>t, IN>>t,
feeder is tripped instantaneously in case IN>> INTOC AR
50N 51N 79
of fault. Arc faults will be extinguished
independently of the fault location. Other
protection relays or fuses do not trip
3
(fuse saving scheme). After successful
Automatic reclosing, all consumers are
supplied with energy again. If there is 52 Fuse opens by
4
unsuccessful reclosing
a permanent fault, further reclosing
cycles will be performed. Depending on I>t, Ip
the setting of the AR, the instantaneous 67
Circuit-breaker opens
by unsuccessful reclosing
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 Fig. 4/14 Auto-reclosure 5
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.
6
Reverse power protection with parallel Infeed Infeed
infeeds A B
If a busbar is supplied by two parallel 7

infeeds and there is a fault in one of the
infeeds, the affected busbar shall be
selectively shut down, so that supply to
52 52
the busbar is still possible through the
remaining infeed. To do this, directional
devices are required, which detect a
67 67N 32R 67 67N 32R
8
short circuit from the busbar towards the 52
infeed. In this context, the directional
time-overcurrent protection is normally 52 52
adjusted over the load current. Low-cur-

rent faults cannot be shut down by this
9
protection. The reverse power protection
can be adjusted far below rated power, Feeder Feeder
and is thus also able to detect reverse
power in case of low-current faults far Fig. 4/15 Reverse power protection with parallel infeeds
below the load current. The reverse
power protection is implemented through
the “flexible protection functions”.
10

Synchrocheck
Where two system sections are inter-
1 connected, the synchrocheck
Busbar
determines whether the connection V2

is permissible without danger to Closing Signal
the stability of the power system. In 52
1
the example, load is supplied from
2 a generator to a busbar through a
transformer. The vector group of
Local/remote
the transformer can be considered
4_16_LSA4114-us.pdf
Transformer control
by means of a programmable angle VT1
2
1)
adjustment, so that no external 25 SYN

2)
adjustment elements are necessary. 81 AR
3 Infeed G
Synchrocheck can be used for
auto-reclosure, as well as for control
functions (local or remote). 1)
Synchrocheck
2)
Automatic reclosing
4 Fig. 4/16 Measurement of busbar and feeder voltage for synchronization
Busbar
5 Protection of a transformer
The high-current stage enables a cur- 59-1 PU ,t
High-voltage
59
rent grading, the overcurrent stages
work as backup protection to subordi-
nate protection devices, and the I>, I>> I>t, I>>t, Ip >t I2>t, I2>>t
6
TRIP
overload function protects the 52 50 51 49 46
transformer from thermal overload. IN>, IN>>

IN>t, IN>>t,
INTOC
Low-current, single-phase faults 50N 51N Inrush blocking
on the low-voltage side, which are

reproduced in the opposite system
7 on the high-voltage side, can be de-
tected with the unbalanced load pro-
52
tection. The available inrush blocking

prevents pickup caused by the inrush 87
currents of the transformer.

8 e.g.
7UT61
52
*
IN>, IN>> IN>t, IN>>t, INTOC

50N 51N
9 52
Busbar
Medium-voltage
TRIP
52 52 52 52
4_17_LSA2203b-us.pdf
I2>>t, I2>t I>, I>> I>t, I>>t, Ip

46 50 51
typical Feeder
10
Unbalanced fault
Fig. 4/17 Typical protection concept for a transformer

Undervoltage-controlled reactive
power protection (QV Protection)
When connecting generating units 1
to the medium-voltage power
system of the operator, a protective Power transformer
disconnection device is required

which takes into account frequency Busbar
and voltage and also evaluates the
Circuit breaker at the power-system connection point
2
reactive power direction. When the Further *
generating unit draws reactive power I>, I>> I-TOC IN>, IN>> IN-TOC
feeders
50 51 50N 51N
from the operator's power system,
Undervoltage-controlled reactive 52 V>, V>> V< f>, f> Q>/ V<
1)
1) Undervoltage
power protection (Q> & V<) links the Tripping
59 27 81
controlled reactive
reactive power with all three phase-
to-phase voltages falling below a Medium-voltage busbar
power protection
3
limiting value using a logical AND
operation.
This ensures that generating units
disconnect from the power system
which additionally burden the power
Generator step-up transformers
4
system during a short circuit or Bus coupler circuit-breaker
prevent that the power system is re- 52 52 52 Decoupling protection
4_18_Visio-QU-Schutz-en.pdf
stored when connecting after a short with V>>, V<, V<<, f>, f< functionen
circuit. The monitoring of the voltage

support also fulfills this function.
5
Using the criteria mentioned above G
3~
G
3~
G
3~ Generators
the QV protection disconnects the
generating unit from the power
system after a programmable time.
Fig. 4/18 Application directional intermittent ground fault protection
6
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 7
stable again.
10


12345 6 7 8 9 10 11 12 13 14 15 16 17 18 19
1 Overcurrent Protection SIPROTEC 7SJ80 7SJ80 - - +
Measuring inputs, binary inputs and outputs

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 see
Housing 1/6 19"; 4 x I, 3 x V, 7 BI, 8 BO (2 Changeover/Form C), 1 life contact 4 next
page
Housing 1/6 19"; 4 x I, 3 x V, 11 BI, 5 BO (2 Changeover/Form C), 1 life contact 8
Measuring inputs, default settings
Iph = 1 A/5 A, IE = 1 A/5 A 1
3 Iph = 1A / 5A, IEE (sensitive) = 0,001 to 1,6A / 0,005 to 8A 2
Auxiliary voltage
DC 24 V / 48 V 1
DC 60 V / 110 V / 125 V / 220 V / 250 V, AC 115 V, AC 230 V 5
4 Construction
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 A
5 Region World, IEC/ANSI, language Englisch (language changeable), standard front

Region US, ANSI, language US-English (language changeable), US front
B
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
6 Region RUS, IEC/ANSI, language Russian (language changeable), standard front

Region CHN, IEC/ANSI, language Chinese (language not changeable), Chinese front
G
K
Port B (at bottom of device, rear)
No port 0
IEC60870-5-103 or DIGSI4/Modem, electrical RS232 1
7 IEC60870-5-103 or DIGSI4/Modem, electrical RS485

IEC60870-5-103 or DIGSI4/Modem, optical 820nm, ST connector
2
3
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
8 MODBUS, optical 820nm, ST connector

DNP 3.0, electrical RS485
9
9
L 0 E
L 0 G
DNP 3.0, optical 820nm, ST connector 9 L 0 H
IEC 60870-5-103, redundant, electrical RS485, RJ45 connector 9 L 0 P
IEC 61850, 100Mbit Ethernet, electrical, double, RJ45 connector 9 L 0 R
9 IEC 61850, 100Mbit Ethernet, optical, double, LC connector

DNP3 TCP + IEC 61850, 100Mbit Ethernet, electrical, double, RJ45 connector
9
9
L 0 S
L 2 R
DNP3 TCP + IEC 61850, 100Mbit Ethernet, optical, double, LC connector 9 L 2 S
PROFINET + IEC 61850, 100Mbit Ethernet, electrical, double, RJ45 connector 9 L 3 R
PROFINET + IEC 61850, 100Mbit Ethernet, optical, double, LC connector 9 L 3 S
IEC 60870-5-104 + IEC 61850, 100Mbit Ethernet, electrical,double, RJ45 connector 9 L 4 R
IEC 60870-5-104 + IEC 61850, 100Mbit Ethernet, optical, double, LC connector 9 L 4 S
MODBUS TCP + IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector 9 L 5 R
MODBUS TCP + IEC 61850, 100 Mbit Ethernet, optical, double, LC connector 9 L 5 S
10 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
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. Short code

12345 6 7 8 9 10 11 12 13 14 15 16 17 18 19
Overcurrent Protection SIPROTEC 7SJ80 7SJ80 - - +
1
3)
Basic version F A
50/51 Time-overcurrent protection, phase I>, I>>, I>>>, Ip
50N/51N Time overcurrent protection, ground IE>, IE>>, IE>>>, IEp
50N(s)/51N(s)1) Sensitive ground fault protection IEE>, IEE>>, IEEp
2
2)
87N High impedance REF
49 Overload protection
46 Negative-sequence system overcurrent protection
37 Undercurrent monitoring
86 Lockout
Parameter changeover
3
Control of circuit breaker
Flexible protection functions (current parameters)
Inrush restraint
51V
Basic functionality + Directional sensitive ground fault, voltage and frequency protection
Voltage dependent inverse-time overcurrent protection
F B 4)
4
67N Directional time-overcurrent protection, ground, IE>, IE>>, IE>>>, IEp
67Ns1) Directional sensitive ground fault protection, IEE>, IEE>>, IEEp
64/59N Displacement voltage
27/59 Under/Overvoltage
81U/O
47
Under/Overfrequency, f<, f>
Phase rotation
5
Flexible protection functions (current and voltage parameters)): Protective function for voltage,
27R/32/55/59R/81R power, power factor, rate-of-frequency change, rate-of-voltage change
4)
Basic functionality + Directional phase & ground overcurrent, F C
6
directional sensitive ground fault, voltage and frequency protection
51V Voltage dependent inverse-time overcurrent protection
67 Directional time-overcurrent protection, phase, I>, I>>, I>>>, Ip
67N Directional time-overcurrent protection, ground, IE>, IE>>, IE>>>, IEp
67Ns1) Sensitive ground-fault protection, IEE>, IEE>>, IEEp
64/59N Displacement voltage
7
27/59 Under/Overvoltage
81U/O Under/Overfrequency, f<, f>
47 Phase rotation
Flexible protection functions (current and voltage parameters): Protective function for voltage,
4)
Basic functionality + Directional phase & ground overcurrent, directional sensitive F F
ground fault, voltage and frequency protection + Undervoltage controlled reactive
power protection + Directional intermittent ground fault protection 8
67 Directional overcurrent protection, phase, I>, I>>, I>>>, Ip
67N Directional overcurrent protection, ground, IE>, IE>>, IE>>>, IEp
67Ns2)
64/59N
27/59
Directional intermittent ground fault protection
Displacement voltage
Under/Overvoltage
9
81U/O Under/Overfrequency, f<, f>
Undervoltage controlled reactive power protection, Q>/V<
47 Phase rotation
Flexible protection functions (current and voltage parameters)): Protective function for voltage,
see
next
page
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) Only if position 6 = 1, 2 or 7

ANSI No. Product description Order No.

12345 6 7 8 9 10 11 12 13 14 15 16
1 Overcurrent Protection SIPROTEC 7SJ80 7SJ80 - -
5)
Basic functionality + Directional phase overcurrent, voltage and FQ
frequency protection + synchrocheck
2 67
27/59
Directional time-overcurrent protection, phase, I>, I>>, I>>>, Ip
Under/Overvoltage (phase-to-phase)
81U/O Under/Overfrequency, f< ,f>
47 Phase rotation
25 Synchrocheck
Flexible protection functions (current and voltage parameters)):
Protective function for voltage, rate-of-frequency change, rate-of-
27R/59R/81R voltage change
3 Automatic Reclosing (AR), Fault Locator (FL)
Without 0
79 With automatic reclosure function 1
FL With FL (only with position 6 = 3, 4 or 8) 2
4 79/FL With automatic reclosure function and FL

(only with position 6 = 3, 4 or 8)
3
5) Only with position 6 = 3 or 4 and position 16 = 0 or 1
10 You will find a detailed overview of the technical data (extract of the manual) under: http://www.siemens.com/siprotec

Connection diagrams
1
F1 IA BO1 C11
C9
F2 C10
F3 I B, IN2
BO2 C14
F4
F5 IC
C13
C12 2
F6
BO3 E1
F7 I N, INS
E2
F8
BO4 E3
E4
BO5 E5
E6
3
C3
C4
BI1
4
C5 BI2
C6
C8
5
E8
E7
= + C1
Power Supply (~)
=
- C2
Port B
6
B
Port A
A
7
Ethernet interface
USB-DIGSI-Interface
4_19_LSA4784us.pdf

250 V
Fig. 4/19 Multifunction protection SIPROTEC 7SJ801
10

Connection diagrams
1
F1 IA BO1 C1 1
F2 C9
C10
F3 I B, IN2
BO2 C1 4
2 F4
F5 IC
C13
C12
F6
BO3 E1
F7 I N, INS
E2
F8
BO4 E3
E4
3 BO5 E5
E6
BO6 D9
D10
BO7 D11
C3
4 C4
BI1
BO8
D12
D13
C5 BI2 D14
C6
C7 BI3
C8 Life Contact E10
5 D1 BI4
E8
E7
D2
= + C1
D3 BI5 Power Supply (~)
D4 =
- C2
6 D5
D6
BI6
Port B
D7 B
BI7 e.g. System interface
D8
Port A
7 A
Ethernet interface
USB-DIGSI-Interface
4_20_LSA4785us.pdf

250 V
10

Connection diagrams
1
F1 IA BO1 C1 1
F2 C9
C10
F3 I B, IN2
BO2 C1 4
F4
F5 IC
C13
C12
2
F6
BO3 E1
F7 I N, INS
E2
F8
BO4 E3
E9 Q2 VA, VAB, Vph-n E4
E11
E12
VB, VBC BO5 E5
E6
3
E13 VC, VN, Vsyn, VX
E14
C3
C4
BI1
4
C5 BI2
C6
C7 BI3
C8 Life Contact E10
E8
E7 5
= + C1
Power Supply (~)
=
- C2
Port B
6
B
Port A
A
7
Ethernet interface
USB-DIGSI-Interface
4_21_LSA4786us.pdf

250 V
10

Connection diagrams
1
F1 IA BO1 C1 1
F2 C9
C10
F3 I B, IN2
BO2 C1 4
2 F4
F5 IC
C13
C12
F6
BO3 E1
F7 I N, INS
E2
F8
BO4 E3
3 E11
E12
VB, VBC BO5 E5
E6
E13 VC, VN, Vsyn, VX BO6 D9
E14 D10
BO7 D11
C3
4 C4
BI1
BO8
D12
D13
C5 BI2 D14
C6
C7 BI3
C8 Life Contact E10
5 D1 BI4
E8
E7
D2
= + C1
D4 =
- C2
6 D5
D6
BI6
Port B
D7 B
D8
Port A
7 A
Ethernet interface
USB-DIGSI-Interface
4_22_LSA4787us.pdf

250 V
10

Connection diagrams
1
F1 IA BO1 C1 1
F2 C9
C10
F3 I B, IN2
BO2 C1 4
F4
F5 IC
C13
C12
2
F6
BO3 E1
F7 I N, INS
E2
F8
BO4 E3
E4
BO5 E5
E6
3
C3
C4
BI1
4
C5 BI2
C6
C7 BI3
C8 Life Contact E10
D1 BI4
E8
E7 5
D2
= + C1
D4 =
- C2
D5
D6
BI6
Port B
6
D7 B
D8
D9 BI8 Port A
D10 A
7
BI9 Ethernet interface

D11
4_23_Visio-kl-uebers-7sx807-us.pdf
D12 BI10
D13 USB-DIGSI-Interface
BI11
D14

250 V

9
10

Connection diagrams
1
F1 IA BO1 C1 1
F2 C9
C10
F3 I B, IN2
BO2 C1 4
2 F4
F5 IC
C13
C12
F6
BO3 E1
F7 I N, INS
E2
F8
BO4 E3
3 E11
E12
VB, VBC BO5 E5
E6
E13 VC, VN, Vsyn, VX
E14
C3
4 C4
BI1
C5 BI2
C6
C7 BI3
C8 Life Contact E10
5 D1 BI4
E8
E7
D2
= + C1
D4 =
- C2
6 D5
D6
BI6
Port B
D7 B
D8
D9 BI8 Port A
7 D10 A
BI9 Ethernet interface

D11
4_24_Visio-kl-uebers-7sx808-us.pdf
D12 BI10
D13 USB-DIGSI-Interface
BI11
D14

250 V

9
10

Connection examples
Connection of current
and voltage transformers
1
A
B
Standard connection C
For grounded networks, the ground 52 52 52

current is obtained from the phase
currents by the residual current F1 IA F2
4_25_LSA4789-en.pdf
circuit. F3 IB F4
F5 IC F6
P2 S2
IN
P1 S1 F7 F8
A B C SIPROTEC
Fig. 4/25 Residual current circuit without directional element

3
A
B
C
4
A
a
5
E9 VA-N
E11 VB-N E12

52 52 52
E13 VC-N E14 6
IA
F1 F2
4_26_LSA4791-en.pdf
IB
F3 F4
IC
F5 F6
7
L l
IN
K k F7 F8
A B C SIPROTEC
Fig. 4/26 Residual current circuit with directional element

8
A
B
For power systems with small earth
currents, e.g. isolated or compen- Surface-/Flush Mounting Housing
C
9
52 52 52
sated systems, the earth current is IA
F1 F2
measured by a zero-sequence current IB
F3 F4
transformer. IC
F5 F6
L l
K k
INs
A B C F8 F7
L l
SIPROTEC 10
K k
Fig. 4/27 Sensitive ground current detection without directional element

Connection examples
Connection for compensated

networks A
1 The figure shows the connection of

A
B
C
two phase-to-ground voltages and
the VE voltage of the broken delta B
winding and a phase-balance neutral da
current transformer for the ground

2
dn
a
current. This connection maintains
maximum precision for directional b
ground-fault detection and must be

used in compensated networks.
LSA4792a-en.pdf
E9 VA-B
E11 VC-B E12
3 52 52 52 E13 VN E14
IA
F1 F2
IB
F3 F4
IC
F5 F6
L l
4 K k
A B C
F8 INs F7
L l
5
SIPROTEC
K k
Fig. 4/28 Sensitive directional ground-fault detection with directional

element for phases
6
A
Sensitive directional ground-fault B
detection. C
A
7 B
da
dn Surface-/Flush Mounting Housing
52 52 52 VN
E13 E14
8 F1
F3
IA
IB
F2
F4
IC
F5 F6
L l
9
K k
A B C
F8 INs F7
L l SIPROTEC
K k
Fig. 4/29 Sensitive directional ground-fault detection
10

Connection examples
Connection for the synchrocheck

function A
If no directional earth-fault protection

B
C
1
A B
is used, connection can be done with a b Surface-/Flush Mounting Housing
just two phase current transformers. 52 52 52
VA-B
For the directional phase short-circuit E9
2
A a
protection, the phase-to-phase
E12
voltages acquired with two primary B
A
b
a
transformers are sufficient. B b E11

VC-B
VSyn
E14
E13
F1
IA
F2
3
IB
4_30_LSA4858-en.pdf
F3 F4
F5 IC F8
L l
K k F7 IN F8 4
A B C SIPROTEC
Fig. 4/30 Measuring of the busbar voltage and the outgoing feeder

voltage for synchronization 5
Further connection examples 6

You´ll find further connection
examples in the current manual or
via www.siemens.com/siprotec
10

Connection types
Overview of connection types

Type of network Function Current connection Voltage connection
1 (Low-resistance) grounded
networks
Time-overcurrent protection
phase/ground non-directional
Residual circuit, with 3 phase-
current transformers required,
–
phase-balance neutral current

transformers possible
(Low-resistance) grounded Sensitive ground-fault protection Phase-balance neutral current –
2 networks
Isolated or compensated Overcurrent protection phases
transformers required
Residual circuit, with 3 or 2 phase- –
networks non-directional current transformers possible
(Low-resistance) grounded Directional time-overcurrent Residual circuit, with 3 phase- Phase-to-ground connection or
networks protection, phase current transformers possible phase-to-phase connection
Isolated or compensated Directional time-overcurrent Residual circuit, with 3 or 2 phase- Phase-to-ground connection or
3 (Low-resistance) grounded
networks
Directional time-overcurrent
protection, ground-faults
Phase-to-ground connection
required
Isolated networks Sensitive ground-fault protection Residual circuit, if ground current 3 times phase-to-ground
4 > 0.05 IN on secondary side,

otherwise phase-balance neutral
connection or phase-to-ground
connection with broken delta
current transformers required winding
Compensated networks Sensitive ground-fault protection Phase-balance neutral current 3 times phase-to-ground
cos j measurement transformers required connection or phase-to-ground
5 winding
Table 4/4 Overview of connection types
10

Overcurrent
Protection 7SJ81
for Low-Power CT and VT Applications
SIPROTEC Compact
Page
1
Description 5/3
2 Applications 5/5
10

for Low-Power CT and VT Applications – Description
Description
The SIPROTEC 7SJ81 provides 4 low-power current transform-
er inputs and optionally 3 low-power voltage transformer 1
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 20 A to 2500 A
can be protected when using low-power current transform-
ers. The following low-power current transformer ratios are 2
suitable for the following primary current operating ranges:
• 300 A / 225 mV for a primary operating current range
of 60 A to 630 A
LSP3.01-0024.eps
• 600 A / 225 mV for a primary operating current range
of 120 A to 1250 A
• 1250 A / 225 mV for a primary operating current range 3
of 250 A to 2500 A
• 100 A / 225mV for a primary operating current range
of 20 A to 200 A
The SIPROTEC 7SJ81 is a multi-functional motor protection
relay. It is designed for protection of asynchronous motors
4
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
Fig. 5/1 SIPROTEC 7SJ81 front view
5
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 6
personnel can react quickly and safely in any situation. This
guarantees a high operational reliability.
Highlights
• Inputs for Low power CTs and VTs according IEC 61869-6 7
(formerly IEC 60044-7 and IEC 60044-8)
• Removable terminal blocks
LSP3.01-0025.eps
• 9 programmable function keys 8

• 6-line display
• USB front port
• 2 additional communication ports 9
Ethernet rings
• Redundancy protocol RSTP for highest availability
• Relay-to-relay communication through Ethernet with Fig. 5/2 SIPROTEC 7SJ81 rear view
IEC 61850 GOOSE
Ethernet with SNTP.
10

for Low-Power CT and VT Applications – Function overview
Protection functions IEC ANSI No.

Instantaneous and definite time-overcurrent protection (phase/neutral) I>, I>>, I>>>, IE>, IE>>, IE>>>; Ip, IEp 50, 50N; 51, 51N
1 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
Overvoltage protection, zero-sequence system V E, V 0> 59N
2 Inrush restraint
Undercurrent monitoring I< 37
Thermal overload protection J> 49
Undervoltage/overvoltage protection V<, V> 27/59
3 Overfrequency/underfrequency protection f<, f> 81O/U
Breaker failure protection 50BF
Phase-balance current protection (negative-sequence protection) I2> 46
Unbalance-voltage protection and/or phase-sequence monitoring V2>, phase sequence 47
4 Automatic reclosing 79
Fault locator FL
Lockout 86
Forward-power, reverse-power protection P<>, Q<> 32
5 Power factor cos j 55
6 Control functions/programmable logic Communication interfaces

• Commands for the ctrl. of CB, disconnect switches • System/service interface
(isolators/isolating switches) –– IEC 61850 Edition 1 and 2
• Control through keyboard, binary inputs, DIGSI 4 or –– IEC 60870-5-103
7 SCADA system
• User-defined PLC logic with CFC (e.g. interlocking).
–– PROFIBUS-DP
–– DNP 3.0
–– MODBUS RTU
–– Redundancy protocol RSTP
• Operational measured values I, V, f
8 • Energy metering values Wp, Wg
• Ethernet interface for DIGSI 4
• Circuit-breaker wear monitoring
• Minimum and maximum values Hardware
• Trip-circuit supervision (74TC) • 4 current inputs
9 • Fuse failure monitor • 0/3 voltage inputs
• 8 oscillographic fault records. • 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
The SIPROTEC 7SJ81 unit is a numerical protection with low Operational indications
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
are stored in the relay to provide the user or operator with 1
all the key data required to operate modern substations.
ensures reliable supply of electrical power to the customers.
The ergonomic design makes control easy from the relay Line protection
front panel. A large, easy-to-read display was a key design
factor. The SIPROTEC 7SJ81 units can be used for line protection
of high and medium-voltage networks with grounded, 2
Control low-resistance grounded, isolated or a compensated neutral
point.
nect devices, grounding switches or circuit-breakers through Transformer protection
The relay provides all the functions for backup protection for
control or automation system (e.g. SICAM).
transformer differential protection. The inrush suppression 3
Programmable logic effectively prevents unwanted trips that can be caused by
inrush currents.
add own functions for automation of switchgear (e.g. inter- Backup protection
user-defined messages. This functionality can form the base SIPROTEC 7SJ81 can be used as a backup protection for a 4
to create extremely flexible transfer schemes. wide range of applications.
Operational measured values Switchgear cubicles for high/medium voltage
Extensive measured values (e.g. I, V), metered values (e.g.

Wp,Wq) and limit values (e.g. for voltage, frequency) provide
of medium-voltage applications. In general, no separate
5
improved system management. measuring instruments (e.g., for current, voltage, frequen-
cy, …) or additional control components are necessary in the
cubicles.
6
Busbar
Local/remote control
Commands/Feedbacks
CFC logic Operational measured values
V, f, P
7
Limits
74TC Trip circuit supervision Flexible protection functions
52 AND Mean value I, V, P, Q,
cos φ, f P<>, Q<> cosφ df/dt
86 Lock out min/max-memory
32 55 81R
Operation Communication module
Metered energy: as counting pulses f<, f>
81U/O
V>
59
V<
27
8
RS232/485/FO/
Ethernet Fault recording Fault Locator
Esc Enter
IEC 60870-5-103 Directional supplement
7 8 9
4 5 6 IEC 61850
1 2 3
PROFIBUS-DP
Fn 0 . Phase sequence
9
DNP 3.0 FL 47
monitoring
MODBUS RTU
I>, I>> I- IN>, IN>>,
TOC IN-TOC
67 67N
I>, I>>, IN>, IN>>,

I>>> I-TOC IN>>> IN-TOC I2> > BF I<
InRush Additional Directional ground

50 51 50N 51N 46 49 50BF 37 fault protection
BLK
INs>,
INs>>
79 AR 67Ns-TOC VN>
50N 51N 67Ns 59N
IN>, IN>>, IN-TOC

IN>>>
AR Automatic reclosing I2> Unbalanced load protection
10
BF Breaker Failure Protection Thermal overload protection
I< Undercurrent monitoring

for Low-Power CT and VT Applications – Application sheets
Protection functions Directional time-overcurrent protection (ANSI 67, 67N)

Directional phase and ground protection are separate func-
1 Overcurrent protection (ANSI 50, 50N, 51, 51N)
tions. They operate in parallel to the non-directional overcur-
This function is based on the phase-selective measurement rent elements. Their pickup values and delay times can be set
of the three phase currents and the ground current (four separately. Definite-time and inverse-time characteristics are
transformers). Three definite time-overcurrent protection offered. The tripping characteristic can be rotated by ± 180
elements (DMT) are available both for the phase and the degrees.
2 ground elements. The current threshold and the delay time By making use of the voltage memory, the directionality can
can be set in a wide range. be determined reliably even for close-in (local) faults. If the
Inverse time-overcurrent protection characteristics (IDMTL) primary switching device closes onto a fault and the voltage
can also be selected and activated. is too low to determine direction, the direction is determined
using voltage from the memorized voltage. If no voltages are
Reset characteristics stored in the memory, tripping will be according to the set
3 Time coordination with electromechanical relays is made characteristic.
easy with the inclusion of the reset characteristics according For ground protection, users can choose whether the direc-
to ANSI C37.112 and IEC 60255-3/BS 142 standards. When tion is to be calculated using the zero-sequence or negative-
using the reset characteristic (disk emulation), the reset pro- sequence system quantities (selectable). If the zero-sequence
cess is initiated after the fault current has disappeared. This voltage tends to be very low due to the zero-sequence impe-
4 reset process corresponds to the reverse movement of the dance it will be better to use the negative-sequence quantities.
Available inverse-time characteristics
5 Characteristics acc. to
Inverse
IEC 60255-3
●
ANSI / IEEE
●
Short inverse ●
6 Moderately inverse ●
7 Inrush restraint
zation of a transformer, the pickup of stages I >, Ip, I >dir Fig. 5/4 D
irectional characteristics of the directional
and Ip dir is blocked. time-overcurrent protection
8 Dynamic settings group switching (Sensitive) directional ground-fault detection

(ANSI 59N/64, 67Ns, 67N)
In addition to the static parameter changeover, the pickup
thresholds and the tripping times for the directional and For isolated-neutral and compensated networks, the direc-
non-directional time-overcurrent protection functions can tion of power flow in the zero sequence is calculated from
9 be changed over dynamically. As changeover criterion, the
the zero-sequence current I0 and zero-sequence voltage V0.
For networks with an isolated neutral, the reactive current
binary input can be selected. component is evaluated; for compensated networks, the ac-
tive current component or residual resistive current is evalu-
Directional comparison protection (cross-coupling)
ated. For special network conditions, e.g. high-resistance
It is used for selective instantaneous tripping of sections grounded networks with ohmic-capacitive ground-fault
fed from two sources, i.e. without the disadvantage of time current or low-resistance grounded networks with ohmic-
delays of the set characteristic. The directional comparison inductive current, the tripping characteristics can be rotated
protection is suitable if the distances between the protection approximately ± 45 degrees (see Fig.5/5).
zones are not significant and pilot wires are available for
10 signal transmission. In addition to the directional compari-
son protection, the directional coordinated time-overcurrent
protection is used for complete selective backup protection.

It has the following functions: circuit. It is also possible to make use of the circuit-breaker
• TRIP via the displacement voltage VE position contacts (52a or 52b) for indication as opposed to
the current flowing through the circuit-breaker.
1
one user-defined characteristic. Automatic reclosing (ANSI 79)
• Each element can be set to forward, reverse or
Multiple re-close cycles can be set by the user and lockout
non-directional.
will occur if a fault is present after the last re-close cycle.
• The function can also be operated in the insensitive mode
as an additional short-circuit protection.
The following functions are available: 2
• 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)
• Initiation of the ARC is dependant on the trip command
selected (e.g. I2>, I>>, Ip, Idir >)
3
• The ARC function can be blocked by activating a binary
input
• The ARC can be initiated from external or by the PLC logic
(CFC) 4
• 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
5
overcurrent elements.
Flexible protection functions

The SIPROTEC 7SJ81 enables the user to easily add up to
20 additional protection functions. Parameter definitions
6
Fig. 5/5 Directional determination using cosine measurements for are used to link standard protection logic with any chosen
compensated networks characteristic quantity (measured or calculated quantity).
(Sensitive) ground-fault detection
(ANSI 50Ns, 51Ns / 50N, 51N)
command, a block function, etc. The mode of operation for
7
For high-resistance grounded networks, a sensitive input current, voltage, power and power factor quantities can be
transformer is connected to a split-core low-power current three-phase or single-phase. Almost all quantities can be
transformer (also called core-balance CT). The function can operated with ascending or descending pickup stages (e.g.
under and overvoltage). All stages operate with protection
priority.
8
Negative-sequence system overcurrent protection (ANSI 46)
By measuring current on the high side of the transformer,
9
processing
5_6_Visio-flexProFunc-us.pdf
(simplified diagram)
Current I measured
the two-element phase-balance current/negative-sequence 4
V measured Time
Pickup
3I0, I1, I2
protection detects high-resistance phase-to-phase faults 3V0, U1, U2 t
TRIP
command
Voltage
and phase-to-ground faults on the low side of a transformer 3 P,Q Threshold
cos φ
(e.g. Dy 5). This function provides backup protection for f
Function 1
Function 2
high-resistance faults through the transformer. df/dt
Function 20
Breaker failure protection (ANSI 50BF)

If a faulted portion of the electrical circuit is not discon- Fig. 5/6 Flexible protection function
nected when a trip command is issued to a circuit-breaker,
another trip command can be initiated using the breaker fail-
ure protection which trips the circuit-breaker of an upstream
10
feeder. Breaker failure is detected if, after a trip command
is issued and the current keeps on flowing into the faulted

Protection functions/stages available are based on the A sudden drop in current, which can occur due to a reduced
available measured analog quantities: load, is detected with this function. This may be due to shaft
1 Function ANSI
I>, IE> 50, 50N Overvoltage protection (ANSI 59)

V<, V>, VE> 27, 59, 59N The two-element overvoltage protection detects unwanted
3I0>, I1>, I2>, I2 / I1>, 3V0>, V1> <, V2 > < 50N, 46, 59N, 47 network and machine overvoltage conditions. The function
2 P> <, Q> < 32 can operate either with phase-to-phase, phase-to-ground,
cos j 55
age. Three-phase and single-phase connections are possible.
f>< 81O, 81U
df / dt > < 81R Undervoltage protection (ANSI 27)
Table 5/3 Available flexible protection functions The two-element undervoltage protection provides protec-
3 For example, the following can be implemented:
tion against dangerous voltage drops (especially for electric
machines). Applications include the isolation of generators
• Reverse power protection (ANSI 32R) or motors from the network to avoid undesired operating
• Rate-of-frequency-change protection (ANSI 81R). conditions and a possible loss of stability. Proper operating
conditions of electrical machines are best evaluated with
4 Trip circuit supervision (ANSI 74TC)
The circuit-breaker coil and its feed lines are monitored via
the positive-sequence quantities. The protection function is
active over a wide frequency range (45 to 55, 55 to 65 Hz).
2 binary inputs. If the trip circuit is interrupted, and alarm Even when falling below this frequency range the function
indication is generated. continues to work, however, with decreased accuracy. The
function can operate either with phase-to-phase, phase-
5 Lockout (ANSI 86) to-ground or positive phase-sequence voltage, and can be
key is used to reset the lockout state. The lockout state is also
stored in the event of supply voltage failure. Reclosure can Frequency protection (ANSI 81O/U)
only occur after the lockout state is reset.
6 Thermal overload protection (ANSI 49)
Frequency protection can be used for overfrequency and
function with an integrated warning/alarm element for
7 temperature and current can be used. The temperature is
8 function considers loading history and fluctuations in load.
can be performed by activating a binary input or by using an
undervoltage element.
Settable dropout delay times
If the relays are used in conjunction with electromechanical Fault locator (ANSI FL)
relays, in networks with intermittent faults, the long dropout
The integrated fault locator calculates the fault impedance
9 times of the electromechanical relay (several hundred milli-
seconds) can lead to problems in terms of time coordination/
kilometers (miles) and in percent of the line length.
the dropout or reset time is approximately the same. This is Customized functions (ANSI 32, 51V, 55 etc.)
why the parameter for dropout or reset times can be defined
for certain functions, such as overcurrent protection, ground Additional functions, which are not time critical, can be im-
short-circuit and phase-balance current protection. plemented using the CFC measured values. Typical functions
include reverse power, voltage controlled overcurrent, phase
Undercurrent monitoring (ANSI 37) angle detection, and zero-sequence voltage detection.
10

Futher functions The devices also offer a new method for determining the
Measured values • Two-point method. 1
The r.m.s. values are calculated from the acquired current The CB manufacturers double-logarithmic switching cycle
and voltage along with the power factor, frequency, active diagram (see Fig. 5/7) and the breaking current at the time
and reactive power. The following functions are available for of contact opening serve as the basis for this method. After
measured value processing: CB opening, the two-point method calculates the remaining
• Currents IL1, IL2, IL3, IN, IEE number of possible switching cycles. Two points P1 and P2 2
only have to be set on the device. These are specified in the
• Voltages V L1, V L2, V L3, V12, V 23, V 31
CB’s technical data.
• Symmetrical components I1, I2, 3I0; V1, V 2, 3V0
• Power Watts, Vars, VA/P, Q, S can be set in order to obtain an alarm if the actual value falls
(P, Q: total and phase selective) below or exceeds the limit value during determination of
• Power factor cos j (total and phase selective) the remaining service life. 3
• Frequency
• Energy ± kWh, ± kVarh, forward and reverse power flow
• Mean as well as minimum and maximum current and volt-
age values
4
Limit values can be monitored using programmable logic
in the CFC. Commands can be derived from this limit value 5
indication.
• Zero suppression P1: Permissible
number of
In a certain range of very low measured values, the value operating cycles
is set to zero to suppress interference. at rated normal
current
6
Metered values P2: Permissible
number of
For internal metering, the unit can calculate an energy operating cycles
metered value from the measured current and voltage at rated short-
values. If an external meter with a metering pulse output
is available, the SIPROTEC 7SJ81 can obtain and process
circuit current
7
metering pulses through an indication input. The metered
values can be displayed and passed on to a control center Fig. 5/7 P
ermissible number of operating cycles as a function of
as an accumulated value with reset. A distinction is made breaking current
between forward, reverse, active and reactive energy. 8
Circuit-breaker wear monitoring/
circuit-breaker remaining service life Commissioning
Methods for determining circuit-breaker contact wear or Commissioning could not be easier and is supported by
the remaining service life of a circuit-breaker (CB) allow CB DIGSI 4. The status of the binary inputs can be read individu- 9
maintenance intervals to be aligned to their actual degree of ally and the state of the binary outputs can be set individu-
wear. The benefit lies in reduced maintenance costs. ally. The operation of switching elements (circuit-breakers,
There is no exact mathematical method to calculate the disconnect devices) can be checked using the switching
wear or the remaining service life of a circuit-breaker that functions of the relay. The analog measured values are
takes arc-chamber’s physical conditions into account when represented as wide-ranging operational measured values.
the CB opens. To prevent transmission of information to the control center
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:
poses can be connected to a control and protection system. 10
• SI
• SI x , with x = 1..3 Test operation
• Si2t. During commissioning, all indications with test tag can be

for Low-Power CT and VT Applications – Application examples
Radial systems
1) Auto-reclosure
1 General hints:
The relay at the far end (D) from the
(ANSI 79) only with
overhead lines Infeed
infeed has the shortest tripping time. 2) Unbalanced load
Relays further upstream have to be protection (ANSI 46) Transformer protection
as backup protection
time-graded against downstream against asymmetrical
2 relays in steps of about 0.3 s. faults

A 52
Busbar

IN>
I>t t I2>t
3
51 51N 46
2)
Busbar
C
* 52
4 I>t
51
IN>
51N
t I2>t
46
Load
5 Busbar
Visio-LAS4839-us.pdf
D
* 52
I>t IN>t I2>t
6 51 51N 46
Load Load
7 Fig. 5/8 Protection concept with overcurrent protection

compensated systems 1) The sensitive current
measurement of the
8 In isolated or compensated systems,

an occurred earth fault can be
earth current should
be made by a zero-
sequence low-power
Infeed
easily found by means of sensitive current transformer
directional earth-fault detection.
9 Busbar
52
I>> I>t
50 51
Visio-LAS4840-us.pdf
IN>t dir.
1) 67Ns
10 Load

Ring-main cable
protection, 100% of the line can be Infeed Infeed
1
protected via instantaneous tripping 52
(ring-main cable). 52 52
For lines with infeed from two sour-

ces, no selectivity can be achieved
I>t
51
IN>t
51N
υ>t
49
I2>t
46 Direct.Compar.Pickup 2
with a simple definite-time overcur-
Overhead line Overhead line Protection as in
rent protection. Therefore, the
or cable 1 or cable 2 the case of line
directional definite-time overcurrent or cable 1
I>t IN>t dir. I>t IN>t
protection must be used. A non- 67 67N 51 51N
directional definite-time overcurrent
protection is enough only in the
corresponding busbar feeders. The 52 52
3
grading is done from the other end 52
respectively.
Advantage: 100% protection 52 52
of the line via 4
instantaneous 67 67N 51 51N
tripping, and easy I>t IN>t dir. I>t IN>t
setting. Overhead line Overhead line Protection as in
Disadvantage: Tripping times
increase towards
I>t
67
IN>t dir.
67N
I>t
51
IN>t
51N
or cable 3
5
the infeed.
52 52
52 6
Visio-LSA4841-us.pdf
52 52
I>t IN>t υ>t I2>t
51 51N 49 46
Load Load 7
10


1 Applicable to distribution busbars Infeed

I>>t0
2 50/50N 51/51N
52
t0 = 50 ms
Busbar
52 52 52
3 I>> I>> I>t I>t
I>t I>>
50/50N 51/51N 50/50N 51/51N 50/50N 51/51N
4
5
solitary systems, emergency power
6 supply in hospitals), it may be neces-
sary to isolate selected consumers Busbar
from the power system in order
to protect the overall system. The
V< f<
overcurrent-time protection functions 52
7
27 81U
are effective only in the case of a
short-circuit. I>, I>>, IN>,
I>>> IN>> I>, Ip INTOC
Overloading of the generator can be
50 50N 51 51N
measured as a frequency or voltage
drop.
8
> I2> Final trip
79M 49 46 86
9 Fig. 5/12 Line feeder with load shedding
10

Automatic reclosing
The auto-reclosure function (AR) has
starting and blocking options. In the
52
Stage can Stage get slower executes the 1
opposite example, the application of the be blocked than the fuse or reclosing for
blocking of the high-current stages is lower protection the hole feeder
devices graduated
cycles. The overcurrent-time protection
is graded (stages I, Ip) according to the 52 52
ON
TRIP
2
grading plan. If an auto-reclosure func-
I>, I>>, I>>> I>t, I>>t, Ip
tion is installed in the incoming supply
Visio-LSA2219c-us.pdf
50 51
of a feeder, first of all the complete
IN>t, IN>>t,
of fault. Arc faults will be extinguished 50N 51N 79
independently of the fault location.
Other protection relays or fuses do
3
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
52 Fuse opens by
unsuccessful reclosing 4
the setting of the AR, the instantaneous I>t, Ip
tripping stage in the infeed is blocked in 67
the first, second or third cycle, i.e., now by unsuccessful reclosing
the grading is effective according to the
grading plan. Depending on the fault
Auto-reclosure 5
Fig. 5/13 Automatic reclosing
the permanent fault will be shut down
definitively.
Infeed
A
Infeed
B
6
Reverse power protection with parallel
infeeds
If a busbar is supplied by two parallel
infeeds and there is a fault in one of the 52 52
7
infeeds, the affected busbar shall be 67 67N 32R 67 67N 32R
8
52
devices are required, which detect a 52 52
Visio-LSA4116a-us.pdf
short circuit from the busbar towards the

infeed. In this context, the directional
time-overcurrent protection is normally
Feeder Feeder
9
can be adjusted far below rated power, Fig. 5/14 Reverse power protection with parallel infeeds
power in case of low-current faults far
below the load current.
The reverse power protection is imple-
mented through the “flexible protection
functions”.
10

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
1 7SJ81 3- -3 +

Housing 1/6 19"; 4 x I, 3 BI, 5 BO (2 Changeover), 1 life contact 1
2 Housing 1/6 19"; 4 x I, 7 BI, 8 BO (2 Changeover), 1 life contact

Housing 1/6 19"; 4 x I, 3 x V, 3 BI, 5 BO (2 Changeover), 1 life contact
2
3
see
next
page
Housing 1/6 19"; 4 x I, 3 x V, 7 BI, 8 BO (2 Changeover), 1 life contact 4
Low Power Measuring Inputs 3
3
Auxiliary voltage
DC 24 V / 48 V 1
DC 60 V / 110 V / 125 V / 220 V / 250 V, AC 115 V / 230 V 5
Construction
4 Region-specific default- and language settings

Region DE, IEC, language German (language changeable) A
Region World, IEC/ANSI, language English (language changeable) B
5 No port
IEC 60870-5-103 or DIGSI 4/modem, electrical RS232
0
1
IEC 60870-5-103 or DIGSI 4/modem, electrical RS485 2
IEC 60870-5-103 or DIGSI 4/modem, optical 820 nm, ST connector 3
6 PROFIBUS DP slave, electrical RS485 9 L 0 A

PROFIBUS DP slave, optical, double ring, ST connector 9 L 0 B
7 DNP 3.0, electrical RS485

DNP 3.0, optical 820 nm, ST connector
9
9
L 0 G
L 0 H
IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector 9 L 0 R
IEC 61850, 100 Mbit Ethernet, optical, double, LC connector 9 L 0 S
8 Port A (at bottom of device, in front)

No Port 0
With Ethernet interface (DIGSI, not IEC 61850), RJ45 connector 6
9 With fault recording, average values, min/max values 3
10

for Low-Power CT and VT Applications – Selection and ordering data
ANSI No. Description Order No. Short code

12345 6 7 8 9 10 11 12 13 14 15 16 17 18 19
7SJ81 3- -3 +
1
2)
Protection functions Basic functionality F A
50 / 51 Definite/Inverse time-overcurrent protection, phase I>, I >>, I>>>, Ip
50N / 51N Instantaneous/Inverse time-overcurrent protection,
50N(s) / 51N(s)1)
ground IE>, IE>>, IE>>>, IEp
Sensitive ground-current protection IEE>, IEE>>, IEEp
2
46 Unbalanced-load protection
37 Undercurrent, underpower
86 Lockout
3
Inrush restraint
3)
Basic functionality + Directional phase & ground overcurrent, F C
67
directional sensitive ground fault,voltage and frequency protection
Directional overcurrent protection phase I >,I >>, Ip
4
67N Directional overcurrent protection ground IE>, IE>>, IEp
67Ns 1) Directional sensitive ground fault protection IEE>, IEE>>, IEEp
59N Displacement voltage
27 / 59 Under/Overvoltage
81U / O
47
Under/Overfrequency f<, f>
Phase rotation
5
Flexible protection functions (current and voltage parameters):
Protective function for voltage, power
32 / 55 / 81R power factor, frequency change
Automatic Reclosing (AR), Fault Locator (FL)

0
6
Without
79 With AR 1
FL 3) With FL 2
79 / FL 3)
7
With AR and FL 3
1) Depending on the connected low-power ground current transformer the function

10
will be either sensitive (INs) or non-sensitive (IN)
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
1 F1 IA BO1 C11
C9
F2 IB C10
BO2 C14
F3 IC C13
C12
2 F4 IN, INS
BO3 E1
E2
BO4 E3
E4
BO5 E5
E6
3
C3 BI1
C4
4 C5
C6
BI2

C8 E8
E7
5 = + C1
Power Supply (~)
=
- C2
6 Port B
B
Port A
A
Ethernet interface
7
USB-DIGSI-Interface
5_15_Visio-Figure-14-us.pdf
Grounding on the case
8
250 V
Fig. 5/15 Connection diagram for SIPROTEC 7SJ811
10

F1 IA BO1 C11
C9
1
F2 IB C10
BO2 C14
F3 IC C13
F4 IN, INS
BO3
C12
E1
2
E2
BO4 E3
E4
BO5 E5
BO6
E6
D9 3
D10
BO7 D11
C3 BI1 D12
C4
C5
C6
BI2
BO8 D13
D14 4
C7 BI3
C8 Life Contact E10
E8
E7
D1
D2
BI4
= +
5
D3 (~) C1
BI5 Power Supply
D4 =
- C2
D5 BI6
D6
D7 BI7
Port B
B 6
D8
Port A
A
Ethernet interface
7
USB-DIGSI-Interface

8
250 V
10

1 F1 IA BO1 C11
C9
VA-N C10
F2 IB
BO2 C14
VB-N C13
F3 IC C12
2 VC-N
BO3 E1
F4 IN, INS
E2
BO4 E3
E4
BO5 E5
E6
3
C3 BI1
C4
4 C5
C6
BI2
C7 BI3
C8 Life Contact E10
E8
E7
5 = + C1
Power Supply (~)
=
- C2
6 Port B
B
Port A
A
Ethernet interface
7
USB-DIGSI-Interface
8
250 V
10

F1 IA BO1 C11
C9
1
VA-N C10
F2 IB
BO2 C14
VB-N C13
2
F3 IC C12
VC-N
BO3 E1
F4 IN, INS
E2
BO4 E3
E4
BO5 E5
3
E6
BO6 D9
D10
BO7 D11
C3 BI1 D12
C4
4
BO8 D13
C5 BI2 D14
C6
C7 BI3
C8 Life Contact E10
E8
E7
D1
D2
BI4
= + C1
5
D4 =
- C2
D5 BI6
6
D6 Port B
D7 B
D8
Port A
A
Ethernet interface
7
USB-DIGSI-Interface
Visio-Figure-17-us.pdf
8
250 V
10

for Low-Power CT and VT Applications – Connection example
Standard connection capabilities
1 52 52 52
Flush Mounting Housing
F1
IA
F2
2 F3
IB
IC
5_19_Visio-SIP0023us.pdf
F4
LPCT LPCT LPCT IN
A B C
SIPROTEC
3
Fig. 5/19 C
onnection to three low power CTs, normal circuit layout - appropriate for
all networks
52 52 52
5 Flush Mounting Housing
F1
IA
F2
IB
6 F3
IC
5_20_Visio-SIP0023us.pdf
F4
LPCT LPCT LPCT IN
A B C SIPROTEC
7
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
10

52 52 52
1
LPCT/LPVT Flush Mounting Housing
R1 1) R2
F1
*
VA-N
*
IA
2
LPCT/LPVT
R1 1) R2
F2
*
VB-N
IB
*
3
LPCT/LPVT
R1 1) R2
F3
*
VC-N
*
IC
4
F4
A B C IN
SIPROTEC 5
*
LPCT
1) R1 and R2 represent the primary voltage divider.
Important! Cable Shield Grounding must be done on the Cable Side!

6
Fig. 5/21 C
onnection for combined low-power current and voltage
transformers in phase L1, L2 and L3
7
10

1 52 52 52
LPVT Flush Mounting
R1 1) R2 Housing
RJ45 Y-Cable
*
F1 VA-N
IA
2 LPVT
R1 1) R2 RJ45 Y-Cable
*
F2 VB-N
IB
LPVT
3 R1 1) R2 RJ45 Y-Cable
*
F3 VC-N
IC
* * *
4 A
LPCT
B
LPCT
C
LPCT
F4
IN
SIPROTEC
5 LPCT
*
6 Fig. 5/22 C
onnection 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 1)
1)
5_23_Visio-Y-cable_us.pdf
Further connection examples 8 7 6 5 4 3 2 1 8 7 6 5 4 3 2 1

RJ45 socket RJ45 socket
From low-power VT From low-power CT
(Voltage divider)
10 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

10

10

Generator and Mo-
tor Protection 7SK80
SIPROTEC Compact
Page
1
Description 6/3
2 Applications 6/5
10

Description
Description
The SIPROTEC 7SK80 is a multi-functional motor protection
relay. It is designed for protection of asynchronous motors 1
The SIPROTEC 7SK80 features “flexible protection functions”.
the user. 2
Therefore protection of change for frequency or reverse
power protection can be realized, for example.
7SK80_W3_de_en.psd
The relay provides circuit-breaker control, further switching
devices and automation functions. The integrated program-
mable logic (CFC) allows the user to add own functions, e.g.
for the automation of switchgear (interlocking). The user is 3
also allowed to generate user-defined messages.
Highlights
4
using DIGSI
• 6-line display
Fig. 6/1 SIPROTEC 7SK80 front view
5
• USB front port
6
Ethernet rings
• Relay-to-relay communication through Ethernet with 7
IEC 61850 GOOSE
Ethernet with SNTP (over Port A or Port B)
LSP3.01-0008.eps
• Number of binary binputs and inary outputs by connec-

tion from up to two SICAM I / O-Units extendable.
8
Fig. 6/2 SIPROTEC 7SK80 rear view
10

Function overview
Protection functions IEC ANSI
1
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 IE dir>, IE dir>>, IEp dir 67N
Directional overcurrent protection, ground (definite / inverse) IEE>, IEE>>, IEEp 67Ns, 50Ns
Displacement voltage, zero-sequence voltage V E, V 0> 59N
2
Undercurrent monitoring I< 37
Temperature monitoring 38
Load jam protection 51M
Locked rotor protection 14
3 Intermittent ground fault protection IIE>
Directional intermittent ground fault protection IIEdir> 67Ns
Overcurrent protection, voltage controlled 51V
Restart inhibit 66 / 86
4 Undervoltage / overvoltage protection V<, V> 27 / 59
Forward power supervision, reverse power protection P<>, Q<> 32
Power factor cos j 55
Overfrequency / underfrequency protection f<, f> 81O / U
5 Circuit-breaker failure protection 50BF
Unbalance-voltage protection and / or phase-sequence monitoring V2>, phase sequence 47
Start-time supervision 48
6 Lockout 86
Rate-of-voltage-change protection dU / dt 27R, 59R

7 Control functions / programmable logic Communication interfaces
• Commands for the ctrl. of CB, disconnect switches • System / service interface
(isolators / isolating switches) –– IEC 61850 Edition 1 and 2
• Control through keyboard, binary inputs, –– IEC 60870-5-103 and IEC 60870-5-104
8 DIGSI 4 or SCADA system –– PROFIBUS-DP
• User-defined PLC logic with CFC (e.g. interlocking). –– DNP 3.0
–– MODBUS RTU
Monitoring functions –– DNP3 TCP
–– PROFINET
9 • Operational measured values V, I, f
• Energy metering values Wp, Wq
–– Ethernet redundancy protocols RSTP, PRP and HSR
• Ethernet interface for DIGSI 4, and extension from up to
• Circuit-breaker wear monitoring two SICAM I / O-Units 7XV5673 as well as a RTD box
• Minimum and maximum values • USB front interface for DIGSI 4.
• Trip-circuit supervision
Hardware
• Fuse failure monitor
• 4 current transformers
• 8 oscillographic fault records
• 0 / 3 voltage transformers
• Motor statistics.
• 3 / 7 binary inputs (thresholds configurable using soft-
10 ATEX100-certification ware)
The Device is available with ATEX100-certification for • 5 / 8 binary outputs (2 changeover)

protection of explosion-proved machines of increased-safety • 0 / 5 RTD inputs
type ”e“ • 1 life contact

Applications
The SIPROTEC 7SK80 unit is a numerical motor protection Motor protection

relay that can perform control and monitoring functions and
The SIPROTEC 7SK80 device is specifically designed to
therefore provide the user with a cost-effective platform for
power system management, that ensures reliable supply of
protect induction-type asynchronous motors. 1
electrical power to the customers. The ergonomic design Line protection
makes control easy from the relay front panel. A large, easy-
to-read display was a key design factor. SIPROTEC 7SK80 units can be used for line protection of
Control
high and medium-voltage networks with grounded, low-
resistance grounded, isolated or a compensated neutral 2
point.
nect devices, grounding switches or circuit-breakers through Transformer protection
control or automation system (e.g. SICAM). The SIPROTEC 7SK80 device provides all the functions for
backup protection for transformer differential protection.
Programmable logic The inrush suppression effectively prevents unwanted trips 3
that can be caused by inrush currents.
add own functions for automation of switchgear (e.g. inter- Backup protection
As a backup protection the SIPROTEC 7SK80 devices are
universally applicable. 4
Operational measured value Switchgear cubicles for high / medium voltage
Extensive measured values (e.g. I, V), metered values All units are designed specifically to meet the requirements
of high / medium-voltage applications. In general, no separate
5
Operational indication
are stored in the relay to provide the user or operator with 6
Busbar

7
52
Commands/Feedbacks
Limits
V, f, P
74TC Trip circuit supervision AND I, V, P, Q,
Mean value
86 Lock out min/max-memory P<>, Q<> cosφ df/dt dV/dt
Operation Communication module RTD-Box

32
f<, f>
55
V>
81R
V<
27R
59R 8
RS232/485/FO/
Ethernet 81U/O 59 27
Fault recording Additional motor protection
IEC 60870-5-103/4 Load Jam
I<
Esc Enter IEC 61850
7 8 9 PROFIBUS-DP 66/86 37 48 51M Directional supplement (Ground)
9
4
1
5
2
6
3
DNP 3.0
Fn 0 . MODBUS RTU
DNP3 TCP 14 Jammed rotor protection 47 Phase sequence
PROFINET Motor statistics
... 38 Storage temperature
IN>, IN>>, IN-TOC
67N
I- IN-
I>, I>>, TO IN>, IN>>, TO
I>>> C IN>>> C I2> > BF
InRush Intermitt. Additional Directional ground
50 51 50N 51N 46 49 50BF 51V fault protection
BLK ground fault
INs>, 67Ns-
INs>> TOC VN>
67Ns-
67Ns 59N
10
50N 51N TOC
IN>, IN>>, IN-TOC
IN>>>
BF Breaker Failure Protection I2> Unbalanced load protection
66/86 Motor restart inhibit > Thermal overload protection
48 Motor starting protection I< Undercurrent monitoring

Application sheets
Protection functions Directional overcurrent protection, ground (ANSI 67N)

Overcurrent protection (ANSI 50, 50N, 51, 51N, 51V) Directional ground protection is a separate function.
1 This function is based on the phase selective measurement
It operates in parallel to the non-directional ground
overcurrent elements. Their pickup values and delay times
of the three phase currents and the ground current (four
can be set separately. Definite-time and inverse-time
transformers). Three definite time-overcurrent protection
characteristics aroffered. The tripping characteristic can be
elements (DMT) are available both for the phase and the
rotated by 0 to ± 180 degrees.
2 ground elements. The current threshold and the delay time
can be set in a wide range. For ground protection, users can choose whether the
direction is to be calculated using the zero-sequence or
Inverse time-overcurrent protection characteristics (IDMTL)
negative-sequence system quantities (selectable). If the
can also be selected and activated. The inverse-time
zero-sequence voltage tends to be very low due to the zero-
function provides – as an option – voltage-restraint or
sequence impedance it will be better to use the negative-
voltage-controlled operating modes
sequence quantities.
3
Reset characteristics
Time coordination with electromechanical relays are made
easy with the inclusion of the reset characteristics according
4 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
5 emulation).
Characteristics acc. to IEC 60255-3 ANSI / IEEE
6 Inverse
Short inverse
● ●
Long inverse ● ● Fig. 6/4 Directional characteristic of the directional time-overcurrent

Moderately inverse ● protection, ground
7 Very inverse ● ●
Table 6/2 Available inverse-time characteristics (Sensitive) directional ground-fault detection

(ANSI 59N / 64, 67Ns, 67N)
Inrush restraint
For isolated-neutral and compensated networks, the
8 If second harmonic content is detected during the energi- direction of power flow in the zero sequence is calculated
zation of a transformer, the pickup of stages I>, Ip, I>ger and from the zero-sequence current I0 and zero-sequence
Ip ger is blocked. voltage V0. For networks with an isolated neutral, the
reactive current component is evaluated; for compensated
Dynamic settings group switching networks, the active current component or residual resistive
9 In addition to the static parameter changeover, the pickup current is evaluated. For special network conditions, e.g.
thresholds and the tripping times for the directional and high-resistance grounded networks with ohmic-capacitive
non-directional time-overcurrent protection functions can ground-fault current or low-resistance grounded networks
be changed over dynamically. As changeover criterion, the with ohmic-inductive current, the tripping characteristics
circuit-breaker position, the prepared auto-reclosure, or a can be rotated approximately ± 45 degrees (see Fig. 6 / 5).
10

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
1
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) 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
3
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 4
half period up to several periods.
–– They can also develop into static faults over prolonged
periods of time (many seconds up to minutes).
compensated networks

Such intermittent ground faults are typically caused by poor
insulation, e.g. due to insufficient water insulation of old
5
implemented: tripping or “signalling only mode”. cables.
It has the following functions: Ground fault functions based on measured values of the
• TRIP via the displacement voltage VE 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 direc-
6
• Each element can be set to forward, reverse or non- tional intermittent ground fault protection function evaluates
directional specifically the ground current impulses and for the direction
determination it refers them to zero voltage.
• The function can also be operated in the insensitive mode
as an additional short-circuit protection. Negative-sequence system overcurrent protection (ANSI 46)
7
(Sensitive) ground-fault detection By measuring current on the high side of the transformer,
(ANSI 50Ns, 51Ns / 50N, 51N) the two-element phase-balance current / negative-sequence
protection detects high-resistance phase-to-phase faults and
transformer is connected to a phase-balance neutral current
phase-to-ground faults on the low side of a transformer (e.g. 8
Dy 5). This function provides backup protection for high-
resistance faults through the transformer.
circuit protection for neutral or residual ground protection. Breaker failure protection (ANSI 50BF)
Intermittent ground fault protection If a faulted portion of the electrical circuit is not discon- 9
nected when a trip command is issued to a circuit-breaker,
Intermittent (re-igniting) faults are caused by poor cable
another trip command can be initiated using the breaker
insulation or water ingress into cable joints. After some time,
failure protection which trips the circuit-breaker of an
the faults extinguish automatically or they develop into
upstream feeder. Breaker failure is detected if, after a trip
permanent short circuits. During the intermitting, neutral
command is issued and the current keeps on flowing into the
point resistances in impedance grounded systems can suffer
faulted circuit. It is also possible to make use of the circuit-
thermal overload.
breaker position contacts (52a or 52b) for indication as
opposed to the current flowing through the circuit-breaker.
10

Application sheets
Flexible protection functions Trip circuit supervision (ANSI 74TC)

SIPROTEC 7SK80 enables the user to easily add up to 20 The circuit-breaker coil and its feed lines are monitored via
1 additional protection functions. Parameter definitions are 2 binary inputs. If the trip circuit is interrupted, and alarm
used to link standard protection logic with any chosen indication is generated.
characteristic quantity (measured or calculated quantity).
The standard logic consists of the usual protection elements Lockout (ANSI 86)
2 command, a block function, etc. The mode of operation for
current, voltage, power and power factor quantities can be also stored in the event of supply voltage failure. Reclosure
three-phase or phase-selective. Almost all quantities can be can only occur after the lockout state is reset.
under and overvoltage). All stages operate with protection Thermal overload protection (ANSI 49)
priority or speed.
3 function with an integrated warning / alarm element for
Measured-value Parameter Standard protection logic temperature and current can be used. The temperature is
processing
Current I measured
(simplified diagram) calculated using a thermal homogeneous body model (per
4 Pickup
V measured Time IEC 60255-8), it considers the energy entering the equip-
Visio-flexProFunc-us.pdf
3I0, I1, I2 TRIP
4
Voltage
3 P,Q Threshold
cos φ
f
Function 1 function considers loading history and fluctuations in load.
Function 2
df/dt
dV/dt
Function 20 Protection of motors requires an additional time constant.
This is used to accurately determine the thermal heating of
5 Fig. 6/6 Flexible protection functions

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
Protection functions / stages available are based on the avail- external RTD-box.
The thermal replica of the overload function is automatically
6 Function
I>, IE>
ANSI
50, 50N
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 Settable dropout delay times
7 P> <, Q> <
cos j
32
55
If the relays are used in conjunction with electromechani-
cal relays, in networks with intermittent faults, the long
f>< 81O, 81U dropout times of the electromechanical relay (several
df / dt > < 81R hundred milliseconds) can lead to problems in terms of time
coordination / grading. Proper time coordination / grading
8 dV / dt> <
27R, 59R
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 over
For example, the following can be implemented: current protection, ground short-circuit and phase-balance
• Reverse power protection (ANSI 32R) current protection.
9 • Rate-of-frequency-change protection (ANSI 81R).
• Rate-of-voltage-change protection (ANSI 27R, 59R).
10
6/8 SIPROTEC Compact · SIEMENSTrafo

SIP 23.01
Wickl mit Erdung
· Edition 5
Application sheets
Motor protection
Restart inhibit (ANSI 66 / 86)

1
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 2
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
3
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). T - TRIP
I STARTUP Motor startup current
4
[s]
T max STARTUP cold max. startup time of motor with
Emergency start-up startup current from cold motor
If the relay determines that a restart of the T max STARTUP warm max. warm motors startup times
motor is not allowed, the relay will issue
a block signal to the closing command, I Pickup Threshold of the function
5
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.
T max STARTUP cold
6
T max STARTUP warm
Cold Motor
Temperature monitoring (ANSI 38)
Warm Motor
Either 5 internal RTD inputs or up to 12 RTD
7
I
inputs through an external RTD box can be I Pickup I STARTUP
applied for temperature detection. Example

for the application with 5 internal RTD Fig. 6/7 Starting time supervision characteristics
inputs: Two RTDs can be applied to each
bearing (the cause of 50 % of typical motor failures). I A2
8
tTRIP tAmax
The remaining RTD is used to measure the ambient tempera- I
ture. Stator temperature is calculated by the current flowing tTRIP = Tripping time
through the stator windings. Alternatively up to 12 RTDs IA = Motor starting current
can be applied using an external RTD box connected either tAmax = Max. permissible starting time
through RS485 on Port B or through Ethernet on Port A. I = Actual current flowing
The RTDs can also be used to monitor the thermal status of Because the flow of current is the cause of the heating of 9
transformers or other pieces of primary equipment. the motor windings, this equation will accurately calculate
the starting supervision time. The accuracy will not be
Starting time supervision / Locked rotor protection
affected by reduced terminal voltage that could cause a pro-
(ANSI 48 / 14)
longed start. The trip time is an inverse current dependant
Starting time supervision protects the motor against characteristic (I2t).
unwanted prolonged starts that might occur in the event Block rotor can also be detected using a speed sensor con-
of exces-sive load torque or excessive voltage drops within nected to a binary input of the relay. If activated it will cause
the motor, or if the rotor is locked. Rotor temperature is an instantaneous trip.
calculated from measured stator current. The tripping time
is calculated according to the following equation:
10

Application sheets
Load jam protection (ANSI 51M) Frequency protection (ANSI 81O / U)

Load jam is activated when a sudden high load is applied Frequency protection can be used for overfrequency and
1 to the motor because of mechanical failure of a pump for underfrequency protection. Electric machines and parts
example. The sudden rise in current is detected by this of the system are protected from unwanted frequency
function and can initiate an alarm or a trip. The overload deviations. Unwanted frequency changes in the network
function is too slow and thus not suitable can be detected and the load can be removed at a specified
frequency setting. Frequency protection can be used over a
2 Unbalanced-load protection (ANSI 46) wide frequency range (40 to 60 (for 50 Hz), 50 to 70
The unbalanced load protection detects a phase failure or (for 60 Hz)). There are four elements (individually set as
load unbalance due to system asymmetry, and protects the overfrequency, underfrequency or OFF) and each element
rotor from impermissible overheating. can be delayed separately. Blocking of the frequency protec-
tion can be performed by activating a binary input or by
Undercurrent monitoring (ANSI 37) using an undervoltage element.
3 A sudden drop in current, which can occur due to a reduced
Customized functions (ANSI 51V, 55 etc.)
that breaks, no-load operation of pumps or fan failure. Additional functions, which are not time critical, can be
implemented using the CFC measured values. Typical
Motor statistics functions include reverse power, voltage controlled overcur-
4 Essential statistical information is saved by the relay during
a start. This includes the duration, current and voltage. The
rent, phase angle detection, and zero-sequence voltage
detection.
relay will also provide data on the number of starts, total
operating time, total down time, etc. This data is saved as Further functions
statistics in the relay.
5 Overvoltage protection (ANSI 59) Measured values
The two-element overvoltage protection detects unwanted The r.m.s. values are calculated from the acquired current
network and machine overvoltage conditions. The function and voltage along with the power factor, frequency, active
can operate either with phase-to-phase, phase-to-ground, and reactive power. The following functions are available
6 positive phase-sequence or negative phase-sequence
voltage. Three-phase and single-phase connections are
for measured value processing:
• Currents IL1, IL2, IL3, IN, IEE
possible. • Voltages VL1, VL2, VL3, V12, V23, V31
Undervoltage protection (ANSI 27) • Symmetrical components I1, I2, 3I0; V1, V2, 3V0
7 The two-element undervoltage protection provides protec-

• Power Watts, Vars, VA / P, Q, S (P, Q: total and phase
selective)
machines). Applications include the isolation of generators • Power factor cos j (total and phase selective)
or motors from the network to avoid undesired operating • Frequency
conditions and a possible loss of stability. Proper operating • Energy ± kWh, ± kVarh, forward and reverse power flow
8 conditions of electrical machines are best evaluated with
voltage values
Even when falling below this frequency range the function • Operating hours counter
continues to work, however, with decrease accuracy. The • Mean operating temperature of the overload function
9 function can operate either with phase-to-phase, phase-
monitored with a current criterion. Three-phase and single- in the CFC. Commands can be derived from this limit value
phase connections are possible. indication
• Zero suppression
In a certain range of very low measured values, the value
is set to zero to suppress interference.
10

Application sheets
Metered values
For internal metering, the unit can calculate an energy
metered value from the measured current and voltage 1
values. If an external meter with a metering pulse output is
available, the 7SK80 can obtain and process metering pulses
played and passed on to a control center as an accumulated
value with reset. A distinction is made between forward, 2
reverse, active and reactive energy.
Expansion of the binary inputs and outputs with

SICAM I / O Unit 7XV5673
To expand binary inputs and outputs, up to two SICAM of operating cycles
I / O Units 7XV5673 can be connected to the SIPROTEC
7SK80. Every SICAM I / O Unit 7XV7653 has 6 binary inputs,
at rated normal
current 3
6 binary outputs and one ethernet switch for cascading. The
of operating cycles
connection to the protection device is established either via at rated short-
the DIGSI Ethernet service interface Port A or via IEC 61850 circuit current
GOOSE to Port B (system interface with EN100 module). 4
Circuit-breaker wear monitoring /
circuit-breaker remaining service life Fig. 6/8 Permissible number of operating cycles as a function of
breaking current
Methods for determining circuit-breaker contact wear or
the remaining service life of a circuit-breaker (CB) allow CB
Commissioning
5
maintenance intervals to be aligned to their actual degree of
wear. The benefit lies in reduced maintenance costs. Commissioning could not be easier and is supported by
There is no exact mathematical method to calculate the DIGSI 4. The status of the binary inputs can be read individu-
wear or the remaining service life of a circuit-breaker that
takes arc-chamber’s physical conditions into account when ally. The operation of switching elements (circuit-breakers, 6
the CB opens. disconnect devices) can be checked using the switching
This is why various methods of determining CB wear have functions of the relay. The analog measured values are
evolved which reflect the different operator philosophies. represented as wide-ranging operational measured values.
• SI
during maintenance, the communications can be disabled 7
• SI x , with x = 1..3 commissioning, all indications with test tag for test pur-
• Si2t. poses can be connected to a control and protection system.
The devices also offer a new method for determining the
Test operation 8
• Two-point method During commissioning, all indications with test tag can be
The CB manufacturers double-logarithmic switching cycle
of contact opening serve as the basis for this method. After 9
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
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.
10

Radial systems
1) Unbalanced load
General hints:
protection (ANSI 46)
Infeed
infeed has the shortest tripping time. against asymmetrical

faults Transformer protection
Relays further upstream have to be
time-graded against downstream
2 A 52
Busbar
I>t IN>t I2>t
3
51 51N 46
1)
Busbar
C
* 52
4 I>t IN>t I2>t

51 51N 46
5 Load
Busbar
D
* 52
6_9_LSA4839-us.pdf
6 I>t
51
IN>t
51N
I2>t
46
Load Load
7 Fig. 6/9 Protection concept with overcurrent protection
1) The sensitive current

measurement of the
8
Infeed
Earth-fault detection in isolated or earth current should be
compensated systems made by core balance
current transformer
In isolated or compensated systems,
an occurred earth fault can be easily
found by means of sensitive direc- Busbar
9 tional earth-fault detection.
52
6_10_LSA4840-us.pdf
I>> I>t
50 51
7XR96 IN>t dir.
1) 67Ns
60/1
10 Load

Small and medium-sized

motors < 1MW
Applicable, with effective and low- 1
6_11_LSA4869-us.pdf
resistance infeed (IE ≥ IN, Motor), to 52
low-voltage motors and high-voltage I>, I>>,
I2>
I>>> IN>t > IStart²t
motors with low-resistance infeed 50 51N 49 48 46
(IE ≥ IN, Motor)
M
2
Fig. 6/11 Protection concept for small sized motors
High-resistance infeed
(IE ≤ IN, Motor) 52 46-
3
1
1) Zero-sequence current transformer I>> > IStart²t PU I<
50 49 48 46 37
2) The sensitive directional earth-
6_12_LSA4870-us.pdf
fault detection (ANSI 67Ns) is only
4
7XR96 IN>t 2)
applicable with the infeed from an 1) 51N 67Ns
isolated system or a system earthed 60/1 A
via Petersen coil. M
Fig. 6/12 Protection concept for medium sized motors 5

Busbar
Generators < 500 kW Medium-voltage
If a zero-sequence current trans-

52
6
former is available for the sensitive
earth-fault protection, the SIPROTEC
6_13_LSA4871-us.pdf
7SK80 relay with the sensitive earth- G

I>t 46-1
current input should be used.
7
IN>t PU
51/51N 46 49
Fig. 6/13 Protection concept for smallest generators with solidly earthed neutral
8
Busbar
Medium-voltage
52 9
6_14_LSA4872-us.pdf
G1
I>t 46-1
IN>t PU
Generator 51/51N 46 49
2
VNom
RN =
* 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
1
Busbar
V-connection are sufficient.
52
2 81
f><
I>t 46-1 PU P> V>
6_15_LSA4873-us.pdf
51 49 46 32 59
IN>t
3 51N
4 Fig. 6/15 Protection concept for small generators
Busbar protection by overcurrent Infeed

Reverse interlocking
5 Applicable to distribution busbars

without substantial (< 0.25 x IN)
backfeed from the outgoing feeders. I>>t0
50/50N 51/51N
6 52
t0 = 50 ms
Busbar
52 52 52
7
I>, I>>, I>, I>>, I>, I>>,
I>>> I>t I>>> I>t I>>> I>t
6_16_LSA4842-us.pdf
50/50N 51/51N 50/50N 51/51N 50/50N 51/51N
8 Fig. 6/16 Busbar protection with reverse interlocking

9 solitary systems, emergency power
supply in hospitals), it may be neces-
Busbar
sary to isolate selected consumers
from the power system in order
to protect the overall system. The V< f<
52 27 81U
overcurrent-time protection functions
short-circuit. Overloading of the I>, I>>,
I>>> IN>> I>, Ip
IN>,
INTOC
generator can be measured as a 50 50N 51 51N
6_17_LSA4876-us.pdf
10 frequency or voltage drop.

> I2> Final trip
49 46 86

Protection of a transformer
The high-current stage enables a Busbar
current grading, the overcurrent

High-voltage
1
stages work as backup protection to 59-1 PU ,t
subordinate protection devices, and 59
the overload function protects the

transformer from thermal overload.
Low-current, single-phase faults TRIP
I>, I>> I>t, I>>t, Ip >t I2>t, I2>>t
2
52 50 51 49 46
on the low-voltage side, which are IN>t, IN>>t,
reproduced in the opposite system on IN>, IN>> INTOC
50N 51N
the high-voltage side, can be detected Inrush blocking
with the unbalanced load protection.

The available inrush blocking prevents
pickup caused by the inrush currents
of the transformer.
87
3
*
e.g.
7UT61
IN>t, IN>>t,
IN>, IN>> INTOC
50N 51N
52 4
Busbar
Medium-voltage
TRIP
52 52 52 52
I2>>t, I2>t
46 5
typical Feeder
6
Unbalanced fault
7
Motor protection
For short-circuit protection, the
Busbar 8
stages I>> and IE>> are available, for
example. Sudden load variations in Rotation V< V> V0>
52 47 27 59 59N
running operation are acquired by the
Iload> function. For isolated systems,
the sensitive earth-fault detection I>, I>>,
I>>> S> 46-1 PU I< ILoad>
9
(IEE>>, V0>) can be used. The stator is 50 49 46 37 51M
protected against thermal overload by

14 Blocked rotor
us, the rotor by I2>, start-time super
49 Motor starting protection
vision and restart inhibit. A locked
rotor is detected via a binary input, 86 Motor restart inhibit
and shut down as fast as required. The IN> IN>>
restart inhibit can be deactivated by 51N or 67N
an “emergency start”.
The undervoltage function prevents
Tachometer M
10
a start when the voltage is too low;
the overvoltage function prevents
insulation damages.
Fig. 6/19 Typical protection concept for an asynchronous high-voltage motor


12345 6 7 8 9 10 11 12 13 14 15 16 17 18 19
1 Motor Protection SIPROTEC 7SK80 7SK80 - - +

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, 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 see
Housing 1/6 19"; 4 x I, 3 x V, 7 BI, 8 BO (2 Changeover / Form C), 1 life contact 4 next
page
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
Measuring inputs, default settings I
Iph = 1 A / 5 A, IE = 1 A / 5 A 1
3 Iph = 1 A / 5 A, IEE (sensitive) = 0,001 to 1,6 A / 0,005 to 8 A

Auxiliary voltage
2
24 V to 48 V 1
DC 60 V to 250 V; AC 115 V; AC 230 V 5
Construction
4 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 A
5
Region World, IEC / ANSI, language English (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
6
G
Region CHN, IEC / ANSI, language Chinese (language changeable), chinese front K
No port 0
IEC 60870-5-103 or DIGSI 4 / Modem, electrical RS232 1
7
IEC 60870-5-103 DIGSI 4 / Modem or RTD-box, electrical RS485 2
IEC 60870-5-103 DIGSI 4 / Modem or RTD-box, optical 820 nm, ST connector 3
PROFIBUS DP slave, optical, double ring, ST connector 9 L 0 B
8
IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector 9 L 0 R
9 DNP3 TCP + IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector 9 L 2 R
L 2 S
DNP3 TCP + IEC 61850, 100 Mbit Ethernet, optical, double, LC connector 9
PROFINET + IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector 9 L 3 R
PROFINET + IEC 61850, 100 Mbit Ethernet, optical, double, LC connector 9 L 3 S
IEC 60870-5-104 + IEC 61850, 100 Mbit Ethernet, electrical,double, RJ45 connector 9 L 4 R
IEC 60870-5-104 + IEC 61850, 100 Mbit Ethernet, optical, double, LC connector 9 L 4 S
MODBUS TCP + IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector 9 L 5 R
MODBUS TCP + IEC 61850, 100 Mbit Ethernet, optical, double, LC connector 9 L 5 S
Port A (at bottom of device, in front)
10 No port
With Ethernet interface (DIGSI, RTD-box, I / O-Unit, not IEC 61850), RJ45 connector
0
6
With fault recording 1
With fault recording, average values, min / max values 3


12345 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20
Motor Protection SIPROTEC 7SK80 7SK80 - - +
1
4)
Basic functionality (contained in all options) H D 0
50 / 51 Overcurrent protection phase I>, I>>, I>>>, Ip
50N / 51N Overcurrent protection ground IE>, IE>>, IE>>>, IEp
50N(s) / 51N(s)1) Sensitive ground fault protection IEE>, IEE>>, IEEp
2
50BF Circuit breaker failure protection
86 Lockout
48 Starting time supervision
37
66 / 86
Undercurrent monitoring
Restart inhibit
3
14 Locked rotor protection
51M Load jam protection
Motor statistics
Control of circuit-breaker 4
Inrush restraint
5)
H E 0
Basic functionality + Directional sensitive ground fault, voltage
and frequency protection + Directional intermittent ground fault
51V
protection
Voltage dependent inverse-time overcurrent protection
5
67N Directional overcurrent protection ground, IE>, IE>>, IE>>>, IEp
67Ns2) Directional intermittent ground fault protection
64 / 59N
6
Displacement voltage
27 / 59 Under / Overvoltage
81 U / O Under / Overfrequency, f<, f>
47 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,
ATEX100-certification
7
with ATEX100-certification 3) for protection of explosion-proved
machines of increased-safety type ”e“ Z X 9 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)
3) If no ATEX100-certification is required, please order without the order No. extension -ZX99
10

Connection diagrams
1
F1 IA BO1 C11
C9
F2 C10
F3 I B, IN2
2 F4
F5 IC
BO2 C14
C13
C12
F6
BO3 E1
F7 I N, INS
E2
F8
BO4 E3
E4
3 BO5 E5
E6
4 C3
C4
BI1
C5 BI2
C6
5 C8 E8
E7
= + C1
Power Supply (~)
=
- C2
6
Port B
B
Port A
7 A
Ethernet interface
USB-DIGSI-Interface
6_20_LSA4784-us.ai

250 V
Fig. 6/20 Motor protection SIPROTEC 7SK801
10

Connection diagrams
1
F1 IA BO1 C11
F2 C9
C10
F3 I B, IN2
BO2 C14
2
F4 C13
F5 IC C12
F6
BO3 E1
F7 I N, INS
E2
F8
BO4 E3
E4
BO5
3
E5
E6
BO6 D9
D10
BO7 D11
C3 BI1 D12
C4
C5 BI2
BO8 D13 4
D14
C6
C7 BI3
C8 Life Contact E10
E8
D1 BI4
E7
5
D2
= + C1
D4 =
- C2
D5
6
BI6
D6 Port B
D7 B
D8
Port A
A Contacts, Ceramic, 2.2 nF,
Ethernet interface
7
USB-DIGSI-Interface
6_21_LSA4785-us.ai

8
250 V
10

Connection diagrams
1
F1 IA BO1 C11
F2 C9
C10
F3 I B, IN2
2 F4
F5 IC
BO2 C14
C13
C12
F6
BO3 E1
F7 I N, INS
E2
F8
BO4 E3
E9 VA, VAB E4
3 E11
E12
VB, VBC BO5 E5
E6
E13 VC, VN, VX
E14
4
C3 BI1
C4
C5 BI2
C6
C8
5
E8
E7
= + C1
Power Supply (~)
=
- C2
6 Port B
B
Port A
7
A
Ethernet interface
USB-DIGSI-Interface
6_22_LSA4874a-en.ai

250 V
10

Connection diagrams
1
F1 IA BO1 C11
F2 C9
C10
F3 I B, IN2
2
BO2 C14
F4 C13
F5 IC C12
F6 BO3 E1
F7 I N, INS E2
F8 BO4 E3
E4
E9 Q2 VA, VAB
BO5
3
E5
E11 VB, VBC
E6
E12
BO6 D9
E13 VC, VN, VX
D10
E14
BO7 D11
C3 D12
C4
BI1
BO8 D13 4
C5 BI2 D14
C6
C7 BI3
C8 Life Contact E10
D1 BI4
E8
E7 5
D2
= + C1
D4 =
- C2
D5
D6
BI6
Port B
6
D7 B
D8
Port A
A
7
Ethernet interface
USB-DIGSI-Interface
6_23_LSA4875-us.ai

8
250 V
10

Connection diagrams
1
F1 IA BO1 C11
F2 C9
C10
F3 I B, IN2
2
BO2 C14
F4 C13
F5 IC C12
F6
BO3 E1
F7 I N, INS
E2
F8
BO4 E3
E4
3 BO5 E5
E6
C3 Life Contact E10

4
BI1
E8
C4 E7
C5 BI2
C6 = +
(~) C1
Power Supply
C7 BI3
=
- C2
C8
5 Port B
B
Port A
6 (+)
(-)
D1
D2
RTD1
Ethernet interface
A
D5 COMP12
USB-DIGSI-Interface Interference Suppression Capacitors at the
(+) D3 Relay Contacts, Ceramic, 2.2 nF, 250 V
RTD2
(-) D4
7 (+) D7
RTD3
(-) D8
D6 COMP34
(+) D9
RTD4
(-) D10
8 (+) D11
RTD5
(-) D12
6_24_LSA4823-us.ai
D13 COMP5
D14 *)
9
10

Connection diagrams
1
F1 IA BO1 C11
F2 C9
C10
F3 I B, IN2
2
BO2 C14
F4 C13
F5 IC C12
F6
BO3 E1
F7 I N, INS
E2
F8
BO4 E3
E9 VA, VAB E4
E11
E12
VB, VBC BO5 E5
E6
3
E13 VC, VN, VX
E14
C3 Life Contact E10

4
BI1
E8
C4 E7
C5 BI2
C6 = +
(~) C1
Power Supply
C7 BI3
=
- C2
C8
Port B
5
B
Port A
(+)
(-)
D1
D2
RTD1
Ethernet interface
A
6
D5 COMP12
RTD2
(-) D4
(+) D7
RTD3
(-) D8
D6 COMP34
(+) D9
RTD4
(-) D10
(+) D11
8
RTD5
(-) D12
6_25_LSA4824-us.ai
D13 COMP5
D14 *)
9
10

Connection examples
and voltage transformers A
1
B
C
Standard connection
52 52 52
For grounded networks, the ground Surface-/Flush Mounting Housing
current is obtained from the phase F1 IA F2

currents by the residual current
2 F3 IB F4
circuit. IC
F5 F6
6_26_LSA4826us.pdf
P2 S2
IN
P1 S1 F7 F8
SIPROTEC
M
3
Fig. 6/26 Residual current circuit without directional element
4 A
B
C
5
a
E9 VA-N
E11 VB-N E12

52 52 52
6 E13 VC-N E14
IA
F1 F2
6_27_LSA4827us.pdf
IB
F3 F4
IC
F5 F6
L l
7 K k F7
IN
F8
SIPROTEC
8 Fig. 6/27 Residual current circuit with directional element for ground

(non directional element for phases)
A
B
9 Surface-/Flush Mounting Housing

C
52 52 52
IA
F1 F2
IB
F3 F4
IC
F5 F6
L l
K k
6_28_LSA4790us.pdf
INs
A B C F8 F7
10 L l
SIPROTEC
K k
Fig. 6/28 Current transformer connections on three current transformers,

earth current of additional summation current transformer

Connection examples
Connection for compensated

networks A
1
B
The figure shows the connection of A
C
two phase-to-ground voltages and

B
the VE voltage of the broken delta da
winding and a phase-balance neutral

current transformer for the ground dn
2
a
current. This connection maintains b
maximum precision for directional
6_29_LSA4792us.pdf
ground-fault detection and must be Surface-/Flush Mounting Housing
used in compensated networks. E9 VA-B
E11 VC-B E12
52 52 52 E13 VN E14
F1
IA
F2
3
IB
F3 F4
IC
F5 F6
L l
K k
4
A B C
F8 INs F7
L l
SIPROTEC
K k
5
(non directional element for phases)
6
A
Sensitive directional ground-fault B
detection. A
C
da 7
dn Surface-/Flush Mounting Housing
52 52 52 VN
E13 E14
F1
F3
IA
IB
F2
F4
8
IC
F5 F6
L l
K k
9
6_30_LSA4793us.pdf
A B C
F8 INs F7
L l SIPROTEC
K k
10

Connection examples
Connection for all types of power

systems
A
1 The illustration shows the connection B

C
of three current transformers and two
voltage transformers in V-connection. Surface-/Flush Mounting Housing
52 52 52
A directional earth-fault protection E9
VA-B
2 is not possible, as the displacement A a
voltage cannot be calculated. B b E12

A a
VC-B
B b E11
IA
F1 F2
IB
6_31_LSA4859us.pdf
F3 F4
3 F5 IC F8
L l
F7 IN F8
K k
SIPROTEC
4 M
Fig. 6/31 Residual circuit with voltage functions

5 (non directional element for phase)
8 Further connection examples

10

Connection types

(Low-resistance) grounded
networks
Overcurrent protection
phase / ground non-directional
– 1
networks
2
(Low-resistance) grounded Directional overcurrent protection, Residual circuit, with 3 phase- Phase-to-ground connection or
networks phase current transformers possible phase-to-phase connection
Isolated or compensated Directional overcurrent protection, Residual circuit, with 3 or 2 phase- Phase-to-ground connection or
networks phase current transformers possible phase-to-phase connection
(Low-resistance) grounded
networks
Directional overcurrent protection,
ground-faults
Phase-to-ground connection
required
3
> 0.05 IN on secondary side,
otherwise phase-balance neutral
connection or phase-to-ground
connection with broken delta 4

winding
5
10

10

Generator and Mo-
tor Protection 7SK81
SIPROTEC Compact
Page
1
Description 7/3
2 Applications 7/5
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 1
transformer inputs. With the same low-power current trans-
former (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 2
transformer ratios are suitable for the following primary
current operating ranges:
• 300 A / 225 mV for a primary operating current range of
LSP3.01-0026.eps
60 A to 630 A
120 A to 1250 A 3
250 A to 2500 A
20 A to 200 A.
The SIPROTEC 7SK81 is a multi-functional motor protection
4
relay. It is designed for protection of asynchronous motors
The relay provides numerous functions to respond flexibly
Fig. 7/1 SIPROTEC 7SK81 front view
5
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 6
states. In combination with up to 9 function keys, the oper-
ating personnel can react quickly and safely in any situation.
This guarantees a high operational reliability.
Highlights 7
• Inputs for low power VTs and CTs according IEC 61869-6
(formerly IEC 60044-7 and IEC 60044-8)
• Removable terminal blocks
LSP3.01-0008.eps
• Binary input thresholds settable using DIGSI (3 stages) 8

• 6-line display
• USB front port 9
Ethernet rings
• Redundancy protocols RSTP for highest availability Fig. 7/2 SIPROTEC 7SK81 rear view
IEC 61850 GOOSE
Ethernet with SNTP.
10

for Low-Power CT and VT Applications - Function overview

Instantaneous and definite time-overcurrent protection (phase/neutral) I>, I >>, I >>>, IE>, IE>>, IE>>>; Ip, IEp 50, 50N; 51, 51N
1 Directional time-overcurrent protection, ground IE dir>, IE dir>>, IEp dir 67N
Directional overcurrent protection, ground (definite/inverse) IEE>, IEE>>, IEEp 67Ns, 50Ns
Displacement voltage, zero-sequence voltage V E, V 0> 59N
2 Undercurrent monitoring I< 37
Temperature monitoring 38
Load jam protection 51M
Locked rotor protection 14
3 Restart inhibit 66/86
Forward-power, reverse-power protection P<>, Q<> 32
Power factor cos j 55
4 Overfrequency/underfrequency protection f<, f> 81O/U
Breaker failure protection 50BF
Unbalance-voltage protection and/or phase-sequence monitoring V2>, phase sequence 47
5 Start-time supervision 48
Lockout 86
6
Control functions/programmable logic Communication interfaces

7 (isolators/isolating switches) –– IEC 61850 Edition 1 and 2
• Control through keyboard, binary inputs, –– IEC 60870-5-103
DIGSI 4 or SCADA system
–– PROFIBUS-DP
–– DNP 3.0
8 Monitoring functions –– MODBUS RTU
• Operational measured values V, I, f –– Redundancy protocol RSTP
• Energy metering values Wp, Wq • Ethernet interface for DIGSI 4, RTD box
9 • Circuit-breaker wear monitoring
• Trip-circuit supervision
• 4 current inputs
• Fuse failure monitor
• 0/3 voltage inputs
• 8 oscillographic fault records
• 3/7 binary inputs (thresholds configurable using software)
• Motor statistics.
• 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 Operational indication

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
are stored in the relay to provide the user or operator with all 1
The ergonomic design makes control easy from the relay Motor protection
front panel. A large, easy-to-read display was a key design
factor. The SIPROTEC 7SK81 device is specifically designed to protect
induction-type asynchronous motors. 2
Control
Line protection
The integrated control function permits control of disconnect
devices, grounding switches or circuit-breakers through SIPROTEC 7SK81 units can be used for line protection of high
the integrated operator panel, binary inputs, DIGSI 4 or the and medium-voltage networks with grounded, low-resistance
grounded, isolated or a compensated neutral point.
control or automation system (e.g. SICAM).
Transformer protection
3
Programmable logic
The integrated logic characteristics (CFC) allow the user to add The SIPROTEC 7SK81 device provides all the functions for
own functions for automation of switchgear (e.g. interlocking) backup protection for transformer differential protection. The
or switching sequence. The user can also generate user-
defined messages. This functionality can form the base to
inrush suppression effectively prevents unwanted trips that
can be caused by inrush currents. 4
create extremely flexible transfer schemes.
Backup protection
Operational measured value As a backup protection the SIPROTEC 7SK81 devices are
5
of high/medium-voltage applications. In general, no separate
6
Busbar

7
52
Commands/Feedbacks
Limits
74TC Trip circuit supervision V, f, P
AND Mean value I, V, P, Q,
min/max-memory P<>, Q<> cosφ df/dt
8
86 Lock out
32 55 81R
Operation Communication module RTD-Box
f<, f> V> V<
RS232/485/FO/ Fault recording Additional motor protection 81U/O 59 27

Load Jam
Esc Enter
Ethernet I<
IEC 60870-5-103 Directional supplement (Ground)
7 8 9 66/86 37 48 51M
4 5 6 IEC 61850
9
1 2 3
PROFIBUS-DP
Fn 0 . Phase sequence
DNP 3.0 14 Jammed rotor protection 47
monitoring
MODBUS RTU Motor statistics
38 Storage temperature
IN>, IN>>, IN-TOC
67N
I- IN-
I>, I>>, TO IN>, IN>>, TO
I>>> C IN>>> C I2> BF
InRush Additional Directional ground
50 51 50N 51N 46 49 50BF fault protection
BLK
Visio-7SK81- fd-us.pdf
INs>, 67Ns-
INs>> TOC VN>
67Ns-
50N 51N 67Ns 59N
TOC
IN>, IN>>, IN-TOC
IN>>>
BF Breaker Failure Protection I2> Unbalanced load protection
10
66/86 Motor restart inhibit Thermal overload protection
48 Motor starting protection I< Undercurrent monitoring

for Low-Power CT and VT Applications - Application sheets
Protection functions Directional overcurrent protection, ground (ANSI 67N)

Directional ground protection is a separate function. It oper-
1 Time-overcurrent protection (ANSI 50, 50N, 51, 51N)
ates in parallel to the non-directional ground overcurrent
This function is based on the phase selective measurement elements. Their pickup values and delay times can be set
of the three phase currents and the ground current (four separately. Definite-time and inverse-time characteristics
transformers). Three definite-time overcurrent protection aroffered. The tripping characteristic can be rotated by
elements (DMT) are available both for the phase and the 0 to ± 180 degrees.
2 ground elements. The current threshold and the delay time For ground protection, users can choose whether the
can be set in a wide range. direction is to be calculated using the zero-sequence or
Inverse-time overcurrent protection characteristics (IDMTL) negative-sequence system quantities (selectable). If the
can also be selected and activated. zero-sequence voltage tends to be very low due to the
zero-sequence impedance it will be better to use the nega-
Reset characteristics tive-sequence quantities.
3 Time coordination with electromechanical relays are made
to ANSI C37.112 and IEC 60255-3 /BS 142 standards. When
using the reset characteristic (disk emulation), the reset pro-
cess is initiated after the fault current has disappeared. This
4 reset process corresponds to the reverse movement of the
5 Characteristics acc. to
Inverse
IEC 60255-3
●
ANSI / IEEE
●
Short inverse ●
6 Moderately inverse ●
Fig. 7/4 Directional characteristic of the directional time-overcurrent
Table 7/2 Available inverse-time characteristics protection, ground
7 Inrush restraint
zation of a transformer, the pickup of stages I>, Ip, I>dir
and Ip dir is blocked.
8 Dynamic settings group switching

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
9 be changed over dynamically. As changeover criterion, the
10

(Sensitive) directional ground-fault detection Phase-balance current protection (ANSI 46)

(ANSI 59N/64, 67Ns, 67N) (Negative-sequence protection)
For isolated-neutral and compensated networks, the direc- By measuring current on the high side of the transformer, 1
tion of power flow in the zero sequence is calculated from the two-element phase-balance current/negative-sequence
the zero-sequence current I0 and zero-sequence voltage V0. protection detects high-resistance phase-to-phase faults
For networks with an isolated neutral, the reactive current and phase-to-ground faults on the low side of a transformer
component is evaluated; for compensated networks, the (e.g. Dy 5). This function provides backup protection for
active current component or residual resistive current is eval- high-resistance faults through the transformer. 2
uated. For special network conditions, e.g. high-resistance
grounded networks with ohmic-capacitive ground-fault Breaker failure protection (ANSI 50BF)
current or low-resistance grounded networks with ohmic- If a faulted portion of the electrical circuit is not discon-
inductive current, the tripping characteristics can be rotated nected when a trip command is issued to a circuit-breaker,
approximately ± 45 degrees (see Fig. 7/5). 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
3
• It has the following functions: command is issued and the current keeps on flowing into
the faulted circuit. It is also possible to make use of the
• TRIP via the displacement voltage VE
circuit-breaker position contacts for indication as opposed to
the current flowing through the circuit-breaker. 4
• Each element can be set to forward, reverse or non- Flexible protection functions
directional SIPROTEC 7SK81 enables the user to easily add up to 20
• The function can also be operated in the insensitive mode additional protection functions. Parameter definitions are
as an additional short-circuit protection. used to link standard protection logic with any chosen 5
current, voltage, power and power factor quantities can be 6
three-phase or phase-selective. Almost all quantities can be
under and overvoltage). All stages operate with protection
priority or speed.
7
Current I measured
4 Pickup
V measured Time
Visio-flexProFunc-us.pdf
3I0, I1, I2 TRIP
8
Voltage
3 P,Q Threshold
cos φ
Function 1
f
Function 2
df/dt
Function 20
dV/dt
Fig. 7/6 Flexible protection functions 9


(ANSI 50Ns, 51Ns / 50N, 51N)
transformer is connected to a split-core low-power current
10

Protection functions/stages available are based on the avail- Thermal overload protection (ANSI 49)
1 Function ANSI function with an integrated warning/alarm element for
I>, IE> 50, 50N temperature and current can be used. The temperature is
V<, V>, VE> 27, 59, 59N
3I0>, I1>, I2>, I2 / I1>, 3V0>, V1> <,V2 > < 50N, 46, 59N, 47
2 P> <, Q> < 32 constantly adjusted according to the calculated losses. The
cos j 55 function considers loading history and fluctuations in load.
f>< 81O, 81U Protection of motors requires an additional time constant.
df / dt > < 81R 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
3 For example, the following can be implemented: 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.
• Rate-of-frequency-change protection (ANSI 81R). If neither internal RTD inputs nor an external RTD-box exist,
it is assumed that the ambient temperatures are constant.
4 Trip circuit supervision (ANSI 74TC)
The circuit-breaker coil and its feed lines are monitored via Settable dropout delay times
2 binary inputs. If the trip circuit is interrupted, and alarm If the relays are used in conjunction with electromechanical
indication is generated. relays, in networks with intermittent faults, the long dropout
times of the electromechanical relay (several hundred milli-
5 Lockout (ANSI 86)
seconds) can lead to problems in terms of time coordination/
All binary output statuses can be memorized. The LED reset grading. Proper time coordination/grading is only possible if
key is used to reset the lockout state. The lockout state is the dropout or reset time is approximately the same. This is
also stored in the event of supply voltage failure. Reclosure why the parameter for dropout or reset times can be defined
can only occur after the lockout state is reset. for certain functions, such as time-overcurrent protection,
6 ground short-circuit and phase-balance current protection.
10

Motor protection
Restart inhibit (ANSI 66/86)

1
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 2
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
3
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.). T - TRIP
I STARTUP Motor startup current
4
[s]
T max STARTUP cold max. startup time of motor with
Emergency start-up startup current from cold motor
If the relay determines that a restart of the T max STARTUP warm max. warm motors startup times
motor is not allowed, the relay will issue
a block signal to the closing command, I Pickup Threshold of the function
5
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.
T max STARTUP cold
6
T max STARTUP warm
Cold Motor
Temperature monitoring (ANSI 38)
Warm Motor
Either 5 internal RTD inputs or up to 12 RTD
7
I
inputs through an external RTD box can be I Pickup I STARTUP
applied for temperature detection. Example

for the application with 5 internal RTD Fig. 7/7 Starting time supervision characteristics
inputs: Two RTDs can be applied to each
bearing (the cause of 50% of typical motor failures).
The remaining RTD is used to measure the ambient tempera- tTRIP
I A2
I
tAmax 8
ture. Stator temperature is calculated by the current flowing
through the stator windings. Alternatively up to 12 RTDs tTRIP = Tripping time IA = Motor starting current
can be applied using an external RTD box connected either tAmax = Max. permissible starting time
through RS485 on Port B or through Ethernet on Port A. I = Actual current flowing
The RTDs can also be used to monitor the thermal status of Because the flow of current is the cause of the heating of 9
transformers or other pieces of primary equipment. the motor windings, this equation will accurately calculate
the starting supervision time. The accuracy will not be
Starting time supervision/Locked rotor protection affected by reduced terminal voltage that could cause a pro-
(ANSI 48/14) longed start. The trip time is an inverse current dependant
Starting time supervision protects the motor against characteristic (I2t).
unwant- Block rotor can also be detected using a speed sensor con-
ed prolonged starts that might occur in the event of exces- nected to a binary input of the relay. If activated it will cause
sive load torque or excessive voltage drops within the motor, an instantaneous trip.
or if the rotor is locked. Rotor temperature is calculated from
measured stator current. The tripping time is calculated
10
according to the following equation:

Load jam protection (ANSI 51M) Frequency protection (ANSI 81O/U)

Load jam is activated when a sudden high load is applied Frequency protection can be used for overfrequency and
1 to the motor because of mechanical failure of a pump for underfrequency protection. Electric machines and parts
example. The sudden rise in current is detected by this of the system are protected from unwanted frequency
function and can initiate an alarm or a trip. The overload deviations. Unwanted frequency changes in the network
function is too slow and thus not suitable. can be detected and the load can be removed at a specified
2 Unbalanced load protection (ANSI 46) a wide frequency range (40 to 60 (for 50 Hz), 50 to 70 (for
The unbalanced load protection detects a phase failure or 60 Hz)). There are four elements (individually set as over-
load unbalance due to system asymmetry, and protects the frequency, underfrequency or OFF) and each element can
rotor from impermissible overheating. be delayed separately. Blocking of the frequency protection
Undercurrent monitoring (ANSI 37) undervoltage element.
3 A sudden drop in current, which can occur due to a reduced Customized functions (ANSI 51V, 55 etc.)
that breaks, no-load operation of pumps or fan failure. Additional functions, which are not time critical, can be im-
Motor statistics include reverse power, voltage controlled overcurrent, phase
4 Essential statistical information is saved by the relay during
a start. This includes the duration, current and voltage. The Further functions
relay will also provide data on the number of starts, total
operating time, total down time, etc. This data is saved as Measured values
5 statistics in the relay.
The r.m.s. values are calculated from the acquired current
Overvoltage protection (ANSI 59) and voltage along with the power factor, frequency, active
and reactive power. The following functions are available for
measured value processing:
6 can operate either with phase-to-phase, phase-to-ground,
• Currents IL1, IL2, IL3, IN, IEE
• Voltages VL1, VL2, VL3, V12, V23, V31
age. Three-phase and single-phase connections are possible. • Symmetrical components I1, I2, 3 I0; V1, V2, 3V0
Undervoltage protection (ANSI 27) • Power Watts, Vars, VA/P, Q, S (P, Q: total and phase
selective)
7 The two-element undervoltage protection provides protec-
• Power factor cos j (total and phase selective)
machines). Applications include the isolation of generators • Frequency
or motors from the network to avoid undesired operating • Energy ± kWh, ± kVarh, forward and reverse power flow
conditions and a possible loss of stability. Proper operating • Mean as well as minimum and maximum current and
8 conditions of electrical machines are best evaluated with
voltage values
Even when falling below this frequency range the function • Mean operating temperature of the overload function
continues to work, however, with decreased accuracy. The • Limit value monitoring
9 function can operate either with phase-to-phase, phase-
monitored with a current criterion. Three-phase and single- indication
phase connections are possible. • Zero suppression
10

Metered values
For internal metering, the unit can calculate an energy me-
tered value from the measured current and voltage values. If 1
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, 2
active and reactive energy.

Methods for determining circuit-breaker contact wear or of operating cycles
maintenance intervals to be aligned to their actual degree
at rated normal
current 3
of wear. The benefit lies in reduced maintenance costs.
of operating cycles
There is no exact mathematical method to calculate the at rated short-
wear or the remaining service life of a circuit-breaker that circuit current
takes arc-chamber’s physical conditions into account when 4
the
CB opens.
This is why various methods of determining CB wear have breaking current
To do justice to these, the relay offers several methods: 5
• SI Commissioning
• SIx, with x = 1..3 Commissioning could not be easier and is supported by
• Si2t. DIGSI 4. The status of the binary inputs can be read individu-
The devices also offer a new method for determining the ally and the state of the binary outputs can be set individu- 6
remaining service life: ally. The operation of switching elements (circuit-breakers,
disconnect devices) can be checked using the switching
• Two-point method functions of the relay. The analog measured values are
The CB manufacturers double-logarithmic switching cycle represented as wide-ranging operational measured values.
diagram (see Fig. 7/8) and the breaking current at the time To prevent transmission of information to the control center 7
of contact opening serve as the basis for this method. After during maintenance, the communications can be disabled
CB opening, the two-point method calculates the remaining to prevent unnecessary data from being transmitted. During
number of possible switching cycles. Two points P1 and P2 commissioning, all indications with test tag for test purposes
only have to be set on the device. These are specified in the can be connected to a control and protection system.
Test operation
8
can be set in order to obtain an alarm if the actual value falls During commissioning, all indications with test tag can be
below or exceeds the limit value during determination of passed to a control system for test purposes.
9
10

for Low-Power CT and VT Applications - Application examples
Radial systems
1) Unbalanced load
General hints:
protection (ANSI 46)
Infeed
infeed has the shortest tripping time. against asymmetrical

faults Transformer protection
Relays further upstream have to be
time-graded against downstream
2 A 52
Busbar
I>t IN>t I2>t
3
51 51N 46
1)
Busbar
C
* 52
4 I>t IN>t I2>t

51 51N 46
5 Load
Busbar
D
* 52
6 I>t
51
IN>t
51N
I2>t
46
Load Load
7 Fig. 7/9 Protection concept with overcurrent-time protection

measurement of the
8 Earth-fault detection in isolated or
compensated systems
be made by a zero-
Infeed
sequence low-power
In isolated or compensated systems, current transformer
an occurred earth fault can be easily
9 found by means of sensitive direc- Busbar

tional earth-fault detection.
52
I>> I>t
50 51
IN>t dir.
1) 67Ns
10 Load

Small and medium-sized

motors < 1MW
Applicable, with effective and low- 1
Visio-LSA4869a-en.pdf
resistance infeed (IE ≥ IN, Motor), to 52
low-voltage motors and high-voltage I>, I>>,
I2>
I>>> IN>t > IStart²t
motors with low-resistance infeed 50 51N 49 48 46
(IE ≥ IN, Motor).
M
2
Fig. 7/11 Protection concept for small motors

High-resistance infeed
3
measurement of the
(IE ≤ IN, Motor) be made by a zero-
sequence low-power 52 46-
current transformer 1
Visio-LSA4870_-us.pdf
I>> > IStart²t PU I<
2) T
he sensitive directional 50 49 48 46 37
earth-fault detection
(ANSI 67Ns) is only
applicable with the
IN>t 2)
4
1) 51N 67Ns
infeed from an isolated
system or a system
earthed via Petersen coil.
M
Fig. 7/12 Protection concept for medium motors 5

Busbar
Generators < 500 kW Medium-voltage
If a core balance current transformer for
sensitive ground-fault protection is available, 52
6
SIPROTEC 7SK80 should be used with
sensitive ground-current input.

G
I>t 46-1
7
IN>t PU
51/51N 46 49
Fig. 7/13 Protection concept for smallest generators with solidly earthed neutral
8
Busbar
Medium-voltage
52 9
G1
I>t 46-1
IN>t PU
Generator 51/51N 46 49
2
VNom
RN =
* 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
1 are enough.
Busbar
52
2 81
f><
I>t 46-1 PU P> V>
51 49 46 32 59
3
IN>t
51N
4 Fig. 7/15 Protection concept for small generators
5 Busbar protection by overcurrent

Infeed
Reverse interlocking
Applicable to distribution busbars

without substantial (< 0.25 x IN) I>>t0
6 50/50N 51/51N
52
t0 = 50 ms
Busbar
7 52 52 52
I>, I>>, I>, I>>, I>, I>>,

I>>> I>t I>>> I>t I>>> I>t
50/50N 51/51N 50/50N 51/51N 50/50N 51/51N
8
Fig. 7/16 Busbar protection with reverse interlocking
10


In unstable power systems (e.g. soli-
tary systems, emergency power supply 1
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 Busbar
2
in the case of a short-circuit. Overload-
ing of the generator can be measured V< f<
52
as a frequency or voltage drop. 27 81U
I>, I>>, IN>,

I>>> IN>> INTOC
3
I>, Ip
50 50N 51 51N
> I2> Final trip
49 46 86

4
5
Motor protection
Busbar
For short-circuit protection, the stages
I>> and IE>> are available, for example.
Sudden load variations in running op- 52
Rotation
47
V<
27
V>
59
V0>
59N
6
eration are acquired by the Iload> func-
tion. For isolated systems, the sensitive I>, I>>,
earth-fault detection (IEE>>, V0>) can I>>> S> 46-1 PU I< ILoad>
7
50 49 46 37 51M
be used. The stator is protected against
thermal overload by υs, the rotor by 14 Blocked rotor
I2>, start-time supervision and restart

Visio-LSA220ba-us.pdf
49 Motor starting protection

inhibit. A locked rotor is detected via
86 Motor restart inhibit
a binary input, and shut down as fast
8
IN> IN>>
as required. The restart inhibit can be
51N or 67N
deactivated by an “emergency start”.
The undervoltage function prevents a Tachometer M
start when the voltage is too low; the
overvoltage function prevents insu-
lation damages.
Fig. 7/18 Typical protection concept for an asynchronous high-voltage motor
9
10

for Low-Power CT and VT Applications - Selection and ordering data

12345 6 7 8 9 10 11 12 13 14 15 16 17 18 19
1 7SK81 3- -3 +

Housing 1/6 19"; 4 x I, 3 BI, 5 BO (2 Changeover), 1 life ontact 1
2
Housing 1/6 19"; 4 x I, 7 BI, 8 BO (2 Changeover), 1 life contact 2
Housing 1/6 19"; 4 x I, 3 x V, 3 BI, 5 BO (2 Changeover), 1 life contact 3 see
Housing 1/6 19"; 4 x I, 3 x V, 7 BI, 8 BO (2 Changeover), 1 life contact 4 next
page
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 3

3
Auxiliary voltage
DC 24 V / 48 V 1
4
DC 60 V / 110 V / 125 V / 220 V / 250 V, AC 115 V, AC 230 V 5
Construction
5 Region-specific default- and language settings

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 or DIGSI 4/modem, electrical RS232
0
1
IEC 60870-5-103 DIGSI 4/modem or RTD-box, electrical RS485 2
IEC 60870-5-103 DIGSI 4/modem or RTD-box, optical 820 nm, ST connector 3
7 PROFIBUS DP slave, optical, double ring, ST connector

MODBUS, electrical RS485
9
9
L 0 B
L 0 D
8 IEC 60870-5-103, redundant, electrical RS485, RJ45 connector

IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector
9
9
L 0 P
L 0 R
Port A (at bottom of device, in front)

9 No port 0
With Ethernet interface (DIGSI, RTD-box, not IEC 61850), RJ45 connector 6

10

for Low-Power CT and VT Applications - Selection and ordering data

12345 6 7 8 9 10 11 12 13 14 15 16 17 18 19
7SK81 3- -3 +
1
2)
Basic functionality H D 0
50 / 51 Overcurrent protection, phase I>, I>>, I>>>, Ip
50N / 51N Overcurrent protection, ground IE>, IE>>, IE>>>, IEp
50N(s) / 51N(s)1)
49
Sensitive ground fault protection IEE>, IEE>>, IEEp
Thermal overload protection
2
74TC Trip-circuit supervision, TCS
50BF Circuit-breaker failure protection,CBFP
86 Lockout
48 Start-time supervision
37 Undercurrent monitoring
66 / 86
14
Restart inhibit
Locked rotor protection
3
51M Load jam protection
Motor statistics
Flexible protection functions (current parameters) 4
Inrush restraint
3)
Basic functionality + Directional sensitive ground fault, H E 0
voltage and frequency protection
67N Directional overcurrent protection for ground-faults, IE>, IE>>, IEp
67Ns1) Senitive ground-fault detection for systems with resonant or isolated
neutral, IEE>, IEE>>, IEEp
5
59N Overvoltage protection
27 / 59 Under-/overvoltage protection V<, V>
81 U / O Under-/overfrequency protection f<, f>
47 Phase rotation
32 / 55 / 81R Flexible protection functions (current and voltage parameters)
Protection function for voltage, power, power factor, frequency 6
change
1) Depending on the connected low-power current transformer the function will be either sensitive (IEE)
10
or non-sensitive (IE).

for Low-Power CT and VT Applications - Connection diagrams
1
F1 IA BO1 C11
C9
F2 IB C10
BO2 C14
2 F3 IC C13
C12
F4 IN, INS
BO3 E1
E2
BO4 E3
E4
3 BO5 E5
E6
C3
4 C4
BI1
C5 BI2
C6
C8
5
E8
E7
= + C1
Power Supply (~)
=
- C2
6 Port B
B
Port A
7 A
Ethernet interface
USB-DIGSI-Interface

250 V
10

1
F1 IA BO1 C1 1
C9
F2 IB C10
BO2 C1 4
F3 IC C13
C12
2
F4 IN, INS
BO3 E1
E2
BO4 E3
E4
BO5 E5
E6
3
BO6 D9
D10
BO7 D11
C3
C4
BI1
BO8
D12
D13
4
C5 BI2 D14
C6
C7 BI3
C8 Life Contact E10
D1 BI4
E8
E7 5
D2
= + C1
D4 =
- C2
D5
D6
BI6
Port B
6
D7 B
D8
Port A
A
7
Ethernet interface
USB-DIGSI-Interface

250 V
10

1
F1 IA BO1 C11
VA-N C9
C10
F2 IB
BO2 C1 4
2 F3
VB-N
IC
C13
C12
VC-N
BO3 E1
F4 IN, INS
E2
BO4 E3
E4
3 BO5 E5
E6
C3
4 C4
BI1
C5 BI2
C6
C7 BI3
C8 Life Contact E10
5 E8
E7
= + C1
Power Supply (~)
=
- C2
6 Port B
B
Port A
7 A
Ethernet interface
USB-DIGSI-Interface

250 V
10

1
F1 IA BO1 C11
VA-N C9
C10
F2 IB
BO2 C1 4
F3
VB-N
IC
C13
C12
2
VC-N
BO3 E1
F4 IN, INS
E2
BO4 E3
E4
BO5 E5
E6
3
BO6 D9
D10
BO7 D11
C3
C4
BI1
BO8
D12
D13
4
C5 BI2 D14
C6
C7 BI3
C8 Life Contact E10
D1 BI4
E8
E7 5
D2
= + C1
D4 =
- C2
D5
D6
BI6
Port B
6
D7 B
D8
Port A
A
7
Ethernet interface
USB-DIGSI-Interface

250 V
10

1
F1 IA BO1 C1 1
C9
F2 IB C10
BO2 C1 4
2 F3 IC C13
C12
F4 IN, INS
BO3 E1
E2
BO4 E3
E4
3 BO5 E5
E6
C3 Life Contact E10

4 C4
BI1
E8
E7
C5 BI2
C6 = +
(~) C1
Power Supply
C7 BI3
=
- C2
C8
5
Port B
B
Port A
6 (+) D1
RTD1
Ethernet interface
A
(-) D2
D5 COMP12
RTD2
(-) D4
7 (+) D7 Grounding on the case
RTD3
(-) D8
D6 COMP34
(+) D9
RTD4
8 (-) D10
Visio-kl-7SK815-Fig 18-us.pdf
(+) D11
RTD5
(-) D12
D13 COMP5
9 D14 *)
*) The shielding of the connecting cable is connected directly to the

shield cap.
10

1
F1 IA BO1 C11
VA-N C9
C10
F2 IB
BO2 C1 4
F3
VB-N
IC
C13
C12
2
VC-N
BO3 E1
F4 IN, INS
E2
BO4 E3
E4
BO5 E5
E6
3
C3 Life Contact E10

C4
BI1
E8
E7 4
C5 BI2
C6 = +
(~) C1
Power Supply
C7 BI3
=
- C2
C8
5
Port B
B
Port A
(+) D1
RTD1
Ethernet interface
A
6
(-) D2
D5 COMP12
USB-DIGSI-Interface
Interference Suppression Capacitors at the
(+) D3
Relay Contacts, Ceramic, 2.2 nF, 250 V
RTD2
(-) D4
(+) D7 Grounding on the case 7

RTD3
(-) D8
D6 COMP34
(+) D9
RTD4
(-) D10
8
Visio-kl-7SK816-Fig 19-us.pdf
(+) D11
RTD5
(-) D12
D13 COMP5
D14 *)
9
*) The shielding of the connecting cable is connected directly to the

shield cap.
10

for Low-Power CT and VT Applications - Connection examples
1 52 52 52 Flush Mounting Housing
F1
IA
F2
2 IB
F3
IC
Visio-Figure-20-M-us.pdf
* * * F4
IN
3 A B C SIPROTEC
M
4
Fig. 7/25 Connection to 3 low-power CTs, normal circuit layout,
appropriate for all networks
5
52 52 52 Flush Mounting Housing
F1
6 IA
F2
IB
F3
IC
F4
* * * IN
SIPROTEC
A B C
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

52 52 52
1
LPCT/LPVT Flush Mounting Housing
R1 1) R2
F1
*
VA-N
IA
2
*
LPCT/LPVT
R1 1) R2
F2
3
*
VB-N
IB
*
LPCT/LPVT 4
R1 1) R2
F3
*
VC-N
IC
* 5
F4
A B C IN
SIPROTEC 6
*
LPCT
1) R1 and R2 represent the primary voltage divider. 7

Fig. 7/27 Connection for combined low-power current and voltage

transformers in phase L1, L2 and L3
8
10

1 52 52 52
LPVT Flush Mounting
Housing
R1 1) R2 RJ45 Y-Cable
F1 VA-N
IA
2 R1 1) R2
LPVT
RJ45 Y-Cable
F2 VB-N
IB
LPVT
3 R1 1) R2 RJ45 Y-Cable
F3 VC-N
IC
SIP.Com_001_en ai
F4
LPCT LPCT LPCT IN
A B C
SIPROTEC
5 LPCT
6 Fig. 7/28 C
onnection 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 Further connection examples
You´ll find further connection 1)

examples in the current manual or 1)
Visio-Y-cable_us.pdf
8 7 6 5 4 3 2 1 8 7 6 5 4 3 2 1
RJ45 socket RJ45 socket
10 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

10

10

Voltage and Frequency
Protection 7RW80
SIPROTEC Compact
Page
1
Description 8/3
2 Applications 8/5
10

Description
Description
The SIPROTEC 7RW80 is a numerical, multi-function relay for
connection to voltage transformers. It can be used in distri- 1
bution 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 2
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.
LSP3.01-0028.eps
The SIPROTEC 7RW80 features “flexible protection functions”.
the user. For example, a rate of change of frequency function
3
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. 4
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
Fig. 8/1 SIPROTEC 7RW80 front view
5
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.
6
Highlights
• 9 programmable function keys 7
• 6-line display
• USB front port
LSP3.01-0029.eps
• 2 additional communication ports 8

Ethernet rings
• Redundancy protocol RSTP for highest availability
IEC 61850 GOOSE
9
Ethernet with SNTP.
Fig.8/2 SIPROTEC 7RW80 rear view
10

Function overview

1 Rate-of-voltage-change protection V E, V 0> 59N 1)
Overfrequency/underfrequency protection f<, f> 81O/U
Load restoration 81LR
Jump of voltage vector Dj>
2 Overexcitation protection V/f 24
Phase-sequence-voltage supervision V2>, phase sequence 47
Synchrocheck 25
Rate-of-voltage-change protection dV / dt 27R/59R
3 Trip circuit supervision AKU 74TC
Lockout 86
4 Control functions/programmable logic Communication interfaces

(isolators/isolating switches) – IEC 61850 Edition 1 and 2
– IEC 60870-5-103
5 • Control through keyboard, binary inputs, DIGSI 4 or
SCADA system – PROFIBUS-DP
– DNP 3.0
– MODBUS RTU
Monitoring functions – Redundancy protocol RSTP
6 • Operational measured values V, f

• Ethernet interface for DIGSI 4
• Minimum and maximum values
• Trip circuit supervision Hardware
• Fuse failure monitor • 3 voltage transformers
7 • 8 oscillographic fault records. • 3/7 binary inputs (thresholds configurable using software)
• 1 life contact
• Pluggable terminal blocks.
8
10
1) Not available if function package “Q” or “E” (synchrocheck) is selected.

Applications
The SIPROTEC 7RW80 unit is a numerical protection device Line protection

that can perform control and monitoring functions and
therefore provide the user with a cost-effective platform for
For the enhancement of the feeder protection the 7RW80
provides several stages for voltage and frequency protection. 1
power system management, that ensures reliable supply of
electrical power to the customers. The ergonomic design Generator and transformer protection
makes control easy from the relay front panel. A large, easy-
to-read display was a key design factor. Through implemented voltage, frequency and overexcitation
Control
protection the SIPROTEC 7RW80 can be used for generators
and transformers in case of defective voltage or frequency
2
control, full load rejection or operation in islanding genera-
tion systems.
the integrated operator panel, binary inputs, DIGSI 4 or the System decoupling and load shedding
Programmable logic
For system decoupling and load shedding the SIPROTEC
7RW80 provides voltage, frequency, rate-of-frequency- 3
change and rate-of-voltage-change protection.
add own functions for automation of switchgear (e.g. inter- Load restoration
user-defined messages. This functionality can form the base For power system recovery, frequency protection and load
restoration are available in SIPROTEC 7RW80.
4
Operational measured value Switchgear cubicles for high/medium voltage

(e.g.Wp,Wq) and limit values (e.g. for voltage, frequency) of high / medium-voltage applications. In general, no
separate measuring instruments (e.g., for current, voltage,
5
frequency, …) or additional control components are neces-
Operational indication sary.
are stored in the relay to provide the user or operator with all
6
Busbar
8
52 25 Synchrocheck
Commands/Feedbacks
Limits
74TC Trip circuit supervision AND
9
Mean value
V/f
V/f dV/dt df/dt
86 Lock out min/max-memory
27R
24 81R
59R
Operation Communication module
Metered energy: as counting pulses f<, f> V> V<
81U/O 59 27
RS232/485/FO/ Fault recording
Esc Enter
Ethernet
IEC 60870-5-103 Δφ> LR
7 8 9
4 5 6 IEC 61850
PROFIBUS-DP Vector jump Load Restoration
Visio-SIP-0001-us.pdf
1 2 3
Fn 0 .
DNP 3.0 47 Phase sequence
MODBUS RTU
59N VN>
1) 10
1) Not available if function package “Q” (synchrocheck) is selected.

Application sheets
Protection functions Overexcitation protection (ANSI 24)

The overexcitation protection serves for detection of an un-
1 Undervoltage protection (ANSI 27)
permissible high induction (proportional to V/f) in generators
The two-element undervoltage protection provides protec- or transformers, which leads to thermal overloading. This
tion against dangerous voltage drops (especially for electric may occur when starting up, shutting down under full load,
machines). Applications include the isolation of generators with weak systems or under isolated operation. The inverse
or motors from the network to avoid undesired operating characteristic can be set via eight points derived from the
2 conditions and a possible loss of stability. Proper operating manufacturer data. In addition, a definite-time alarm stage
conditions of electrical machines are best evaluated with and an instantaneous stage can be used. For calculation of
the positive-sequence quantities. The protection function the V/f ratio, frequency and also the highest of the three
is active over a wide frequency range of 25 to 70 Hz. The line-to-line voltages are used. The frequency range that can
function can operate either with phase-to-phase, phase-to- be monitored comprises 25 to 70 Hz.
ground or positive phase-sequence voltage. Three-phase
3 and single-phase connections are possible. In addition a
user definable curve with up to 20 value pairs is available.
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
The two-element overvoltage protection detects unwanted jump in the voltage. This is measured by means of a delta
4 network and machine overvoltage conditions. The function
process. The command for opening the generator or coupler
circuit-breaker will be issued if the set threshold is exceeded.
age. Three-phase and single-phase connections are possible. Flexible protection functions
In addition, a user definable curve with up to 20 value pairs SIPROTEC 7RW80 enables the user to easily add up to 20
5 is available. additional protection functions. Parameter definitions are
used to link standard protection logic with any chosen
Frequency protection can be used for overfrequency and un- The standard logic consists of the usual protection elements
derfrequency protection. Electric machines and parts of the such as the pickup set point, the set delay time, the TRIP
6 system are protected from unwanted frequency deviations. command, a block function, etc.
Unwanted frequency changes in the network can be de-
tected 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 e
lements
7 (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.
8 Load restoration
The load restoration function provides an automatic recon-
nection of power system parts when the system frequency
has recovered after load shedding. Four load restoration dV/dt
9 stages are available. They can be switched on and off SIP-0002.en.ai
separately. If the frequency conditions allow the assumption

of sufficient generation resources, the load restoration
function will consecutively reconnect small load parts at The mode of operation for voltage quantities can be three-
specified time intervals. phase 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.
10

Application sheets
Protection functions/stages available are based on the Further functions

available measured analog quantities:
Function ANSI
Measured values
1
V<, V>, VE> 27, 59, 59N The r.m.s. values are calculated from the acquired voltages
3V0>, V1> <, V2> < 59N, 47 along with the frequency. The following functions are avail-
able for measured value processing:
f>< 81O, 81U
df / dt > <
dV / dt
81R
27R/59R
• Voltages VL1, VL2, VL3, VL1L2, VL2L3, VL3L1
• Symmetrical components V1, V2, V0
2
• Frequency
• Mean as well as minimum and maximum voltage values
For example, the following can be implemented: • Operating hours counter
• Rate-of-frequency-change protection (ANSI 81R) • Limit value monitoring
• Rate-of-voltage-change protection (ANSI 27R/59R). Limit values can be monitored using programmable logic 3
Synchrocheck, synchronizing function (ANSI 25) indication
When closing a circuit-breaker, the units can check • Zero suppression
whether two separate networks are synchronized. Voltage-,
frequency- and phase-angle-differences are checked to
is set to zero to suppress interference. 4
determine whether synchronous conditions exist.
Commissioning
Lockout (ANSI 86) Commissioning could not be easier and is supported by
DIGSI 4. The status of the binary inputs can be read individu-
5
also stored in the event of supply voltage failure. Reclosure ally. The operation of switching elements (circuit-breakers,
can only occur after the lockout state is reset. disconnect devices) can be checked using the switching
Trip circuit supervision (ANSI 74TC)
The circuit-breaker coil and its feed lines are monitored via
represented as wide-ranging operational measured values.
6
2 binary inputs. If the trip circuit is interrupted, and alarm
indication is generated.
commissioning, all indications with test tag for test purposes
Customized functions can be connected to a control and protection system.
7
Additional functions can be implemented using CFC or Test operation
flexible protection functions.
During commissioning, all indications with test tag can be
8
10


In unstable power systems (e.g. Overexcitation protection
1 solitary systems, emergency power 52
V>
V>> V/f=f(t)
supply in hospitals), it may be neces- 59 24
sary to isolate selected consumers 7RW80
from the power system in order to
protect the overall system. V< V>
2 The overcurrent protection functions

f<>
81
V<<
27
V>>
59
are effective only in the case of a 7RW80
short-circuit.
Overloading of the generator can be Network coupling 52
drop. 52 52 52
3 Δφ> f<>
V<
V<<
V>
V>> LR f<>
V<
V<<
V>
V>>
SIP-0015a-en.pdf
Vector jump 81 27 59 Load Restoration 81 27 59
7RW80 7RW80 M
Network decoupling Load shedding
4
Fig. 8/5 Application example 7RW80
5
50
Load shedding with rate-of-
Hz
frequency-change protection
f
6 From the measured frequency, the

frequency difference is determined fm
t
over a time interval. It corresponds to
the momentary frequency change. 49
fa
It is thus possible to quickly detect
7 any major load drops in the power
system, to disconnect certain
fb
SIP-0016.de.ai
consumers from the system, and fc
to restore the system to stability.
Unlike frequency protection, rate-of- 48
0 1 2 3 4 5
8 frequency-change-protection already
reacts before the pickup threshold of Fig. 8/6 Load shedding
t
the frequency protection is reached.

The pickup value depends on the ap-
plication, and follows the conditions
9 of the power system. The rate-of-
frequency-change protection function
can also be used for the purposes of
system decoupling.
10

Synchrocheck
connected, the synchrocheck Busbar 1
determines whether the connection
is permissible without danger to V2
the stability of the power system. In Closing Signal
the example, load is supplied from 52
a generator to a busbar through a 1
2
the transformer can be considered
by means of a programmable angle
Local/remote
adjustment, so that no external control
Transformer
adjustment elements are necessary. V1 1)
2
Synchrocheck can be used for 25 SYN
3
SIP C-0022-en.pdf
2)
81 AR
functions (local or remote). Infeed G
1)
2)
Synchrocheck
Automatic reclosing
4
Fig. 8/7 Measurement of busbar and feeder voltage
for synchronization
5
10


12345 6 7 8 9 10 11 12 13 14 15 16 17 18 19
1 7RW80 0- - +
Housing, binary inputs and outputs

Housing 1/6 19", 3x V, 3 BI, 5 BO 1) , 1 life contact 1
2 Housing 1/6 19", 3x V, 7 BI, 8 BO 1) , 1 life contact 2
see
next
Rated auxiliary voltage
page
DC 24 V / 48 V 1
DC 60 V / 110 V / 125 V / 220 V / 250 V, AC 115 V, AC 230 V 5
3 Unit version
Surface mounting housing, screw-type terminal B
4
Region-specific default- and language settings
Region DE, IEC, language German 2), standard front A
Region World, IEC/ANSI, language English 2), standard front B
Region US, ANSI, language US-English 2), US front C
Region FR, IEC/ANSI, language French 2), standard front D
5 Region World, IEC/ANSI, language Spanish 2), standard front

Region World, IEC/ANSI, language Italian 2), standard front
E
F
Region RUS, IEC/ANSI, language Russian 2), standard front G
Region CHN, IEC/ANSI, language Chinese 3), chinese front K
6 Port B (at bottom of device, rear)

No port 0
IEC 60870-5-103 or DIGSI 4/modem, optical 820 nm, ST connector 3
7 PROFIBUS DP slave, electrical RS485

PROFIBUS DP slave, optical, double ring, ST connector
9
9
L 0 A
L 0 B
8 DNP 3.0, optical 820 nm, ST connector

IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector
9
9
L 0 H
L 0 R
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


12345 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20
7RW80 0- - D 0+
1
Voltage and frequency protection A
64 / 59N Displacement voltage
81U / O
47
Under/Overfrequency
Phase rotation
2
86 Lockout
27R / 59R / 81R Flexible protection functions (voltage parameters): Rate-of-frequency
change, rate-of-voltage change
Voltage, frequency protection and load restoration B 3
81U / O Under/Overfrequency
Load restoration
47
74TC
86
Phase rotation
Trip circuit supervision
Lockout
4
27R / 59R / 81R Flexible protection functions (voltage parameters):
Rate-of-frequency change, rate-of-voltage change
Voltage, frequency protection and synchrocheck C
5
25 Synchrocheck
47 Phase rotation
74TC
86
Trip circuit supervision
Lockout 6
7
Voltage, frequency, overexcitation protection and vector jump D
24 Overexcitation
8
Vector jump
47 Phase rotation
86 Lockout
27R / 59R / 81R Flexible protection functions (voltage parameters):
Rate-of-frequency change, rate-of-voltage change 9
Voltage, frequency, overexcitation protection and vector jump, E
load restoration and synchrocheck
24 Overexcitation
Vector jump
Load restoration
25 Synchrocheck
47 Phase rotation
86 Lockout
10

Connection diagrams
1
E9 Q2 VA, VAB, Vph-n BO1 C11
C9
E11 VB, VBC C10
E12
BO2 C14
2 E13
E14
VC, VN, Vsyn, VX C13
C12
C3 BI1 BO3 E1
C4 E2
C5 BI2 BO4 E3
C6 E4
3 C7
C8
BI3 BO5 E5
E6
Life Contact E10

E8
4
E7
= + C1
Power Supply (~)
=
- C2
5
Port B
B
Port A

A
Ethernet interface

6 USB-DIGSI-Interface
8_8_SIP-0011us.pdf
250 V
Fig. 8/8 Voltage and frequency protection SIPROTEC 7RW801
10

Connection diagrams
1
E9 Q2 VA, VAB, Vph-n BO1 C11
C9
E11 VB, VBC C10
E12
BO2 C14
E13
E14
VC, VN, Vsyn, VX C13
C12 2
C3 BI1 BO3 E1
C4 E2
C5 BI2 BO4 E3
C6 E4
C7
C8
BI3 BO5 E5
E6 3
BO6 D9
D1 BI4 D10
D2
BO7 D11
D3 BI5
D4
D5
BO8
D12
D13 4
BI6 D14
D6
D7 BI7
D8 Life Contact E10
E8
E7 5
= + C1
Power Supply (~)
=
- C2
Port B
B
6
Port A
A
Ethernet interface
Contacts, Ceramic, 2.2 nF, 7
USB-DIGSI-Interface
8_9_SIP-0012us.pdf

8
250 V
Fig. 8/9 Voltage and frequency protection SIPROTEC 7RW802
10

Connection examples
Standard connection
A
1 B
C
Housing
52 52 52
E9 VA
2 A B
E11 VB
E12
8_10_SIP-0006us.pdf
a b VC
E13
E14
SIPROTEC
A B C
3 Fig. 8/10 Example for connection type "VAN, VBN, VCN" load-side voltage connection
A
B
4 A
C
B
da
dn
5
a
52 52 52 b
8_11_SIP-0007us.pdf
6 E9 VA-B
E11 VC-B E12
E14 VN E13
A B C SIPROTEC
7 Fig. 8/11 Voltage transformer connections to two voltage transformers

(phase-to-phase voltages) and broken data winding (da-dn)
A
Connection Vx
8
B
C
Housing
52 52 52
E9 VA-B
9 A B
E12
VC-B
E11
5_12_SIP-0008us.pdf
a b Vx
E13
E14
SIPROTEC
10 A B
a b
A B C
Fig. 8/12 Example for connection type "VAB, VBC, Vx"

Connection examples
Connection for synchrocheck

A
1
B
C
A B
a b Housing
52 52 52
VA-B
E9
A B
E12
VC-B
2
E11
8_13_SIP-0010us.pdf
a b VSyn
E14
E13
SIPROTEC
A B C
3
Fig. 8/13 Example for connection type “VAB, VBC, VSYN”
A
B 4
C
A
52 52 52 B
b Housing 5
a E9 VPh-N
A B
a b E12
V-Transformer2
E11
6
8_14_SIP-0009us.pdf
VSyn
E13
E14
A B C SIPROTEC
Fig. 8/14 Example for connection type "Vph-n, Vsyn".

The connection can be established at any one of the three phases.
7
The phase must be the same for Vph-n and Vsyn.
8
Further connection examples
You´ll find further connection 9

via www.siemens.com/siportec
10

10

Feeder Protection
7SC80
SIPROTEC Compact
1
Page
Description 9/3
2 Applications 9/5
Construction and hardware 9/6
Transformers 9/7
Function description 9/8
3 Application examples 9/14
Connection diagrams 9/22
4 Connection examples 9/26
5
SNTP Server/Master 9/31
10

Description
Description
1
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.
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 2
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.
The integrated programmable logic (CFC) allows the user to 3
SIP-COM-01.tif
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
4
messages.
The upgrade of device and communication firmware is also
possible via Ethernet.
Highlights
• Support of feeder automation applications, e.g. fault isolation
and service restauration
Fig. 9/1 SIPROTEC 7SC80 front view with HMI
5
• Designed for harsh environment
• Extended temperature range –50 °C up to 85 °C
6
• Open for all different communication technologies, e.g.
radio, which are used for feeder automation
• Integrated GPS or IRIG/B module is available for time
synchronisation
• Remote access for firmware and parameter updates
• Fulfills NERC/CIP and BDEW security requirements
• A web based HMI provides complete remote control of the
7
device
• 6-line display
• Integrated switch for low-cost and redundant optical 8
rings.
SIP-COM-02.tif
Devices can be connected directly with each other at

electrical modules
• Parallel running communication protocols
• Redundancy protocols RSTP, PRP and HSR for highest
9
availability
• Jump detector for currents and voltages
• Extended CFC capabilities Fig. 9/2 SIPROTEC 7SC80 side view with detached HMI
• 24 km Single mode interface
• RTU version without protection features
• Pluggable terminals • Relay-to-relay communication through Ethernet with
10
• Secondary current transformers values (1 A / 5 A) settable IEC 61850 GOOSE
using DIGSI • Stainless steel housing for flush or surface mounting
• Buffer battery exchangeable without opening the housing • Millisecond-accurate time synchronization through
• USB front port Ethernet with SNTP
• Inputs for Low power CTs and VTs according IEC 61869-6
(formerly IEC 60044-7 and IEC 60044-8).

Function overview
Protection Functions IEC Norm ANSI Norm

Protection function for 3-pole tripping (3-pole)
1 Unbalanced-load protection I2> 46

Negative-sequence system overcurrent protection I2>, I2/11> 46
Definite time-overcurrent protection I> 50/50N
2 Instantaneous tripping at switch onto fault SOFT

Sensitive ground-current protection INs> 50Ns
Circuit-breaker failure protection CBFP 50BF
Inverse time-overcurrent protection IP, INp 51/51N
Cold load pickup 51C
3 Trip-circuit supervision
Lockout
AKU 74TC
86
Restricted ground-fault protection ΔIN 87N
Synchrocheck, synchronizing function 25
4 Undervoltage protection
Phase-sequence-voltage supervision
U<
L1, L2, L3
27
47
Overvoltage protection, negative-sequence system V2>
Voltage dependent overcurrent protection t=t(I)+V< 51V
5 Power factor
Overvoltage protection
cos j
V>
55
59/59N
Overvoltage protection, zero-sequence system V0> 59N
Measuring-voltage failure detection 60FL
6 Directional time-overcurrent protection, phase I>, ∠ (V,I) 67
Table 9/1 Abstract - Function Overview Further functions: current manual or via relay selector
7 Control functions / programmable logic Communication interfaces

• Commands for the ctrl. of CB, disconnect • Ethernet electrical and optical
switches (isolators/isolating switches) (multimode or singlemode)
8 • Control through keyboard, binary inputs,

DIGSI 4 or SCADA system
• IEC 61850 Edition 1 and 2
• DNP3 TCP
• User-defined PLC logic with CFC • PROFINET
(e.g. interlocking).
• IEC 60870-5-104
9 Monitoring functions • Ethernet redundancy protocols RSTP, PRP and HSR

• USB front interface for DIGSI 4
• Operational measured values V, I, f
• Energy metering values Wp, Wq • Serial DNP3 RS485 module.
• Circuit-breaker wear monitoring • 4 current transformers
• Fuse failure monitor • 1/6 voltage transformers
• Max. 40 oscillographic fault records • 12/20 binary inputs
10
• Trip circuit supervision • 8/15 binary outputs
• Load professional for up to 20 different operating mea- • 1 life contact
sured values • Pluggable current and voltage terminal blocks
• Connection option for low-power current and
voltage transformers.

Applications
The feeder protection SIPROTEC 7SC80 is a numerical Operational indication

protection device that can perform control and monitoring
1
functions and therefore provides the user with a cost-
are stored in the relay to provide the user or operator with
effective platform for power system management, that
Device operation was designed according to ergonomic Line protection
aspects. Top priority was given to good display readability
and large function keys. The 32 LEDs allow displaying
numerous states and alarms.
The SIPROTEC 7SC80 units can also be used for line protec-
tion of medium-voltage distribution feeders with grounded, 2
low-resistance grounded, isolated, or compensated neutral.
Control
Transformer protection
The device provides all the functions for backup protection
3
for transformer differential protection. The inrush suppres-
sion effectively prevents unwanted trips that can be caused
systems control (e.g. SICAM).
by inrush currents. The high-impedance restricted ground-
Programmable logic fault protection detects short-circuits and insulation faults
on the transformer.
locking), switching sequence or of the distribution system.
Backup protection 4
As a backup protection the SIPROTEC 7SC80 devices are
The user can also generate user-defined messages.
Operational measured values
5
Extensive measured values, metered values and limit
values provide improved system management as well as
of high / medium-voltage applications. In general, no
commissioning.
separate measuring instruments (e.g., for current, voltage,
frequency, …) or additional control components are
necessary.
6
Busbar
Local/remote control
Commands/Feedbacks
CFC logic Operational values V<
27
V>
59
F1-F4
81 V /O
7
Limits
74TC Trip-circuit supervision
AND I, V, P, Q, 25 Synchrocheck
Mean values
cos φ, f
86 Lockout Min/max- memory Flexible protection functions
52
Device operation Communication
module
- Ethernet
Sectionalizer
function
87L Current-jump detection
P<>,Q<> cos φ df/dt du/dt

8
- IEC 61850
- DNP3 TCP
32 55 81R 27R
59R
- Profinet IO
- IEC60870-5-104 V< V> F1-F4
Supervision Fault locator
27 59 81 V /O
9
- DNP3 Master
60 CTS
60 VTS
Time Directional supplement
synchronization
- GPS
- SNTP
1-pole/3-pole 21FL 47
Phase-rotation
operation supervision
- IRIG-B
INs-1,
I>, I>>, INs-2,
50-1, 50N-1, I>>>, INs-3,
50-2, 50N-2, IN- I-TOC INs-TOC
50-3 I-TOC 50N-3 TOC I2 > ϑ> BF I< 1-4 1-4
50 51
1-4
50N 51N
1-4
46 49 InRush BLC 50BF 51c 37 51V 67 67N
79 AREC
Suppl. determination of ground-
fault direction 10
50N 51N 50Ns 51Ns 87N 67Ns 59N
50N-1, IN-TOC INs-1, INs-TOC REF INs-1, VN>
50N-2, 1-4 INs-2 INs-2,
50N-3 INs-TOC

Construction and hardware
Housing with many advantages
1
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
2
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
SIP-COM-04.tif
SIP-COM-03.tif
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.
3 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 Fig. 9/4 Process termial Fig. 9/5 Current terminal
keys that can be used to configure shortcuts for menu
operations or other applications (see Fig. 9/6).
4 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
5
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
6 operational indications, protection indications, fault records,

primary and secondary values.
You can print or save this data.
The operation panel/HMI is not mandatory for the correct
SIP-COM-05.tif
functioning of the SIPROTEC 7SC80. It can be attached or
7 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.
Fig. 9/6 WebMonitor
SIPROTEC 7SC80 is suited for panel flush mounting or panel
8
surface mounting.
The SIPROTEC 7SC80 variants are always equipped with at
Current terminals – single cables
least one single voltage input Vx. This input can be used e.g.
to detect line voltage of a single phase.
Cable cross-sections AWG 14-12 (2.6 mm2 to 3.3 mm2)
An optional internal GPS module can be ordered to provide
9
When using lugs AWG 14-10 (2.6 mm2 to 6.6 mm2)
high accuracy time synchronization to the device. The GPS
Permissible tightening torque 2.7 Nm
coordinates of the device can e.g. be provided to a control
Stripping length 10 mm to 11 mm (0.39 in to 0.43 in) center.
(for solid conductor) Only solid copper wires may be
used. The SIPROTEC 7SC80 devices can be equipped with either an
electrical or an optical Ethernet module. IEC 61850 is always
Process terminal connections
available on the module and optionally together with one of
Cable cross-sections AWG 18-12 (1.0 mm2 to 2.5 mm2) the protocolls IEC 60870-5-104, PROFINET IO or DNP3 TCP.
Permissible voltages 300 V The optical module can be equipped with single mode ports
Permissible currents 5A to bridge distances up to 24 km, the well known integrated
10 Only solid copper wires may be
used.
Ethernet switch functionality is of course included.
The electrical module can be used in a chain mode to con-
Permissible tightening torque 0.4 - 0.5 Nm
nect another Ethernet based device or 7SC80 directly to a
Stripping length 7 mm (0.28 in) 7SC80.
Table 9/2 Wiring specifications for process connection As an option a serial DNP3 module is available.

Transformers
Low-power transformer terminals Low-power voltage transformers
1
The SIPROTEC 7SC80 is available in two hardware configura- Resistive voltage dividers are provided as low-power voltage
tions, featuring 3 inputs for connecting low-power current transformers. You can generally connect all sensors that
transformers (if the ground current has to be measured support the following SIPROTEC 7SC80 specifications:
separately, the input Vx can be used) and optionally 3 inputs
for voltage transformers. Here, the low-power voltage Measuring range 100 mV - 250 V AC
(measuring accuracy +/- 1mV at 25°C)
2
transformers are connected to the standard voltage trans-
former inputs. The required measuring range is activated via Input impedance 1.2 MOhms (mismatches can be corrected
in the 7SC80 parameters if necessary)
parameter set. Capacitive voltage dividers are supported as
well. Rated voltage 500m V - 40 V
Thermal rating 230 V continuous
Low-power current transformers
Cable 2-pole shielded, open cable end
You can generally connect all sensors to the low-power
current transformer inputs that support the following
SIPROTEC 7SC80 specifications: This enables various rated operating voltage ranges depend-
3
ing on the sensors used.
Measuring range 20 mV - 50 V AC
(measuring accuracy +/- 1 mV at 25°C)
Input impedance
Rated voltage
40 kOhms
200 mV - 20 V at rated current
4
Thermal rating 200 V for 10s
Cable 2-pole shielded, open cable end
IC_SG_Spannungssensor_W3.sRGB.png
This enables various rated operating current ranges depend-
ing on the sensors used. To prevent early saturation, the
overcurrents to be expected must also be observed in the
low-power transformers.
6
Fig. 9/8 Voltage transformer
7
IC_SG_Stromsensor_W3_sRGB.png
Fig. 9/7 Current transformer 9

For protection related purpose the usability of the sensors has to be checked.
The following low-power transformers can be ordered directly via MLFB:
Type MLFB Ratio Description
Phase current sensor 6MD2320-0GA00-1AA0 300 A / 225 mV ext. 200 % split core transformer for cable systems; internal diameter 55 mm;
10
accuracy 1, 5P10; impedance > 20 kOhms
Ground current sensor 6MD2320-0AF00-1AA0 60 A / 225 mV sensor split core transformer for cable systems; internal diameter
120 mm; accuracy 1; impedance > 20 kOhms
Voltage sensor 10 kV 6MD2320-0AA04-1AA0 10 kV / √3 -> 3.25/√3 for T-connector with C-taper; accuracy 1, rated burden 200 kOhms
Voltage sensor 20 kV 6MD2320-0AA07-1AA0 20 kV / √3 -> 3.25/√3 for T-connector with C-taper; accuracy 1, rated burden 200 kOhms
Table 9/3 Available low-power transformers

Function description
Protection functions comparison protection, the directional coordinated time-

overcurrent protection is used for complete selective backup
1 Battery monitor protection.
The DC 24/48 V auxiliary voltage version allows monitor- Available inverse-time characteristics
ing an external 24 V or 48 V battery. The DC voltage is
measured directly and provided as measured value. The Characteristics acc. IEC 60255-3 ANSI / IEEE
to
2
battery is tested periodically. For this purpose, the external
battery loader is deactivated temporarily, and after a short Normal invers ● ●
waiting time, an external load impedance is connected to Short inverse ●
the battery. The battery voltage before and after the test is ● ●
Long inveres
measured. If the voltage difference is higher than a given
threshold, a message can be generated. A number of other
battery-related messages is available. The battery status is
3 also indicated by a special battery LED. Extremely inverse ●

●
Overcurrent protection (ANSI 50, 50N, 51, 51N, 51V)

This function is based on the phase-selective measurement Moreover there are further recloser inverse-time characteris-
of the three phase currents and the ground current (four
4
tic curves available.
transformers). Three definite time-overcurrent protection
elements (DMT) are available both for the phase and the Directional time-overcurrent protection (ANSI 67, 67N)
ground elements. The current threshold and the delay
Direction determination in the 7SC80 is phase-selective and
time can be set in a wide range. 4 inverse-time overcurrent
separate for phase and earth faults. Three stages each for phase
protection characteristics (IDMTL) are available and can also
5 be selected and activated independently.
and earth operate in parallel to the non-directional overcurrent
stages and are adjustable in response value and delay time inde-
Reset characteristics pendently of these. Optionally, inverse directional overcurrent
protection characteristics (AMZ) - up to 4 AMZ curves for phase
Time coordination with electromechanical relays are made
and earth - can be switched in. The tripping characteristic can
6 to ANSI C37.112 and IEC 60255-3 / BS 142 standards. When
using the reset characteristic (disk emulation), the reset pro-
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
cess is initiated after the fault current has disappeared. This
closes onto a fault and the voltage is too low to determine
reset process corresponds to the reverse movement of the
direction, the direction is determined using voltage from the
7 Inrush restraint
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
The relay features second harmonic restraint. If second
direction is to be calculated using the zero-sequence or
harmonic content is detected during the energization of
negative-sequence system quantities (selectable). If the
8
a transformer, the pickup of stages (I>, Ip, I>dir and Ip dir is
zero-sequence voltage tends to be very low due to the
blocked.
zero-sequence impedance it will be better to use the nega-
Dynamic setting change tive- sequence quantities.
The pickup thresholds and the trip times of the directional
9 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.
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 Fig. 9/9 Directional characteristics of the directional
time-overcurrent protection

(Sensitive) directional ground-fault detection Phase-balance current protection (ANSI 46)

(ANSI 59N/64, 67Ns, 67N) (Negative-sequence protection)
For isolated-neutral and compensated networks, the direc- By measuring current on the high side of the transformer, 1
tion of power flow in the zero sequence is calculated from the two-element phase-balance current/negative-sequence
the zero-sequence current I0 and zero-sequence voltage V0. protection detects high-resistance phase-to-phase faults and
For networks with an isolated neutral, the reactive current phase-to-ground faults on the low side of a transformer. This
2
component is evaluated; for compensated networks, the function provides backup protection for high-resistance faults
active current component or residual resistive current is through the transformer.
evaluated.
For special network conditions, e.g. high-resistance
(ANSI 50Ns, 51Ns / 50N, 51N)
grounded networks with ohmic-capacitive ground-fault
current or lowresistance grounded networks with ohmic- For high-resistance grounded networks, a sensitive input
inductive current, the tripping characteristics can be rotated transformer is connected to a phase-balance neutral current
approximately ± 45 degrees (see Fig.9/10). transformer (also called core-balance CT). The function can
3
implemented: tripping or “signalling only mode”. circuit protection for neutral or residual ground protection.
It has the following functions: Breaker failure protection (ANSI 50BF)
• TRIP via the displacement voltage VE
• Three instantaneous elements and four stantaneous
If a faulted portion of the electrical circuit is not disconnected 4
elements trip command can be initiated using the breaker failure pro-
• Each element can be set to forward, reverse or non- tection which trips the circuit-breaker of an upstream feeder.
5
directional Breaker failure is detected if, after a trip command is issued
• The function can also be operated in the insensitive mode the current keeps on flowing into the faulted circuit. It is also
as an additional short-circuit protection. 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)
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

10
LSA4115-de.ai
Fig. 9/11 High-impedance restricted ground-fault protection

4 Pickup
V measured Time
3I0, I1, I2 OFF-

3V0, V1, V2 t Command
Voltage4 P,Q Threshold
cos φ
Function 1
f
Function 2
df/dt
Function 20
The voltage is measured by detecting the current through priority.

the (external) resistor R at the sensitive current measure-
1 ment input IEE. The varistor V serves to limit the voltage in
the event of an internal fault.
Protection functions/stages available are based on the avail-
It limits the high instantaneous voltage spikes that can
occur at current transformer saturation. At the same time, Function ANSI
2
this results to smooth the voltage without any noteworthy I>, IE> 50, 50N
reduction of the average value. V<, V>, VE> 27, 59, 59N
If no faults have occurred and in the event of external or 3I0>, I1>, I2>, I2 / I1>, 3V0>, V1> <, V2 > < 50N, 46, 59N, 47
through faults, the system is at equilibrium, and the voltage
P> <, Q> < 32
through the resistor is approximately zero. In the event of
cos j 55
internal faults, an imbalance occurs which leads to a voltage
and a current flowing through the resistor R. f>< 81O, 81U
3 The same type of current transformers must be used and

must at least offer a separate core for the high-impedance
df / dt > < 81R
dI / dt > < current jump function
restricted ground-fault protection. They must have the Table 9/5 Available flexible protection functions
same transformation ratio and approximately an identical
4
knee-point voltage. They should also have only minimal For example, the following can be implemented:
measuring errors.
Auto-reclosure (ANSI 79) • Rate-of-frequency-change protection (ANSI 81R)
Multiple re-close cycles can be set by the user and lockout • Rate-of-voltage-change protection (ANSI 27R/59R)
will occur if a fault is present after the last re-close cycle.
5 The following functions are available: • Simplified differential protection via IEC 61850 GOOSE
communication.
• 1/3-pole ARC for all types of faults
• Separate settings for phase and ground faults Synchrocheck, synchronizing function (ANSI 25)
• Multiple ARC, one rapid auto-reclosure (RAR) and up to When closing a circuit-breaker, the units can check
6 nine delayed auto-reclosures (DAR)

• Initiation of the ARC is dependant on the trip command
whether two separate networks are synchronized. Voltage-,
frequency- and phase-angle-differences are checked to
selected (e.g. I2>, I>>, Ip, Idir>) determine whether synchronous conditions exist.
• The ARC function can be blocked by activating a binary input
Trip circuit supervision (ANSI 74TC)
7
• The ARC can be initiated from external or by the PLC logic
(CFC) One or two binary inputs can be used for monitoring the
circuit-breaker trip coil including its incoming cables. An alarm
• The directional and non-directional elements can either
signal is generated whenever the circuit is interrupted.
be blocked or operated non-delayed depending on the
auto-reclosure cycle Lockout (ANSI 86)
8 • If the ARC is not ready it is possible to perform a dynamic

setting change of the directional and non-directional
overcurrent elements
also stored in the event of supply voltage failure. Reclosure
• All types of curves can be combined together with various can only occur after the lockout state is reset.
overcurrent elements in different ARC cycles
9 • An additional new input interface is available for entering Thermal overload protection (ANSI 49)
various ARC parameters. To protect cables and transformers, an overload protection
Flexible protection functions function with an integrated warning/alarm element for
temperature and current can be used. The temperature is
SIPROTEC 7SC80 devices enables the user to easily add up
to 20 additional protection functions. Parameter definitions
are used to link standard protection logic with any chosen
function considers loading history and fluctuations in load.
10
current, voltage, power and power factor quantities can be
three-phase or single-phase. Almost all quantities can be
under and over voltage). All stages operate with protection

Settable dropout delay times deviations. Unwanted frequency changes in the network
1
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 mil-
liseconds) can lead to problems in terms of time coordination/
2
the dropout or reset time is approximately the same. This is
why the parameter for dropout or reset times can be defined
undervoltage element.
for certain functions such as overcurrent protection, ground
short-circuit and phase-balance current protection. Fault locator (ANSI FL)
Undercurrent monitoring (ANSI 37) The integrated fault locator calculates the fault impedance
A sudden drop in current, which can occur due to a reduced
kilometers (miles) and in percent of the line length.
3
Customized functions (ANSI 32, 51V, 55 etc.)
Overvoltage protection (ANSI 59) Additional functions, which are not time critical, can be im-
4
The two-element overvoltage protection (possible per
include reverse power, voltage controlled overcurrent, phase
phase)detects unwanted network and machine overvoltage
conditions. The function can operate either with phase-
to-phase, phase-to-ground, positive phase-sequence or Sectionalizer
negative phase-sequence voltage.
This function can automatically isolate fault current sections
Undervoltage protection (ANSI 27) of a distribution circuit once an upstream breaker or recloser
has interrupted the fault current. The sectionalizer function
5
The two-element undervoltage protection provides protec-
has no capacity to break fault current itself, so it is usually
needed as an alignment with recloser. When the recloser
machines). Applications include the isolation of generators
opens for the last time, which has been preset to the
or motors from the network to avoid undesired operating
conditions and a possible loss of stability. Proper operating
sectionalizer, the sectionalizer opens and isolates the faulty
section of line.
6
conditions of electrical machines are best evaluated with
Further functions
Even when falling below this frequency range the function
continues to work, however, with decreased accuracy. The Measured values
7
function can operate either with phase-to-phase, phase-
to-ground or positive phase-sequence voltage, and can be The Load profile function records historical measured
monitored with a current criterion. Three-phase and single- values. With this function, you can obtain a load profile with
8
phase connections are possible. desired data such as the measured values, demand values,
minimum/maximum values, and energy values of the cur-
1-pole operation rent, voltage, power, and frequency. The following functions
are available for measured value processing:
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.
9
Frequency protection can be used for overfrequency and
10

• Currents IL1, IL2, IL3, IN, IEE takes arc-chamber’s physical conditions into account when
• Voltages UL1, UL2, UL3, U12, U23, U31 the CB opens.
1 • Symmetrical components I1, I2, 3I0; U1, U2, 3U0 This is why various methods of determining CB wear have
• Various phase angles
• Power Watts, Vars, VA/P, Q, S (P, Q: total and phase selec-
• SI
tive)
2 • Power factor (cos ϕ), (total and phase selective)
• SIx, with x = 1..3
• Si2t.
• Frequency
• Energy ± kWh, ± kVarh, forward and reverse power flow The devices also offer a new method for determining the
voltage values • Two-point method
3 • Operating hours counter The CB manufacturers double-logarithmic switching cycle

of contact opening serve as the basis for this method. After
• DC voltage measurement of an external battery CB opening, the two-point method calculates the remaining
• Measurement of the internal device temperature number of possible switching cycles. Two points P1 and P2
4 • Limit value monitoring only have to be set on the device. These are specified in the
Limit values can be monitored using programmable logic CB’s technical data.
in the CFC. Commands can be derived from this limit value All of these methods are phase-selective and a limit value
indication can be set in order to obtain an alarm if the actual value falls
• Zero suppression below or exceeds the limit value during determination of
5 In a certain range of very low measured values, the value

Metered values
For internal metering, the unit can calculate an energy me-
6 tered value from the measured current and voltage values. If
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
7 with reset. A distinction is made between forward, reverse,
active and reactive energy.
Binary I/O extension with SICAM I/O-Unit 7XV5673
8
To extend binary inputs and binary outputs for SIPROTEC P1: Permissible number
7SC80 up to two SICAM I/O-Units 7XV5673 can be added. of operating cycles
at rated normal
Each SICAM I/O-Unit 7XV7653 is equipped with 6 binary current
inputs and 6 binary outputs and an Ethernet switch for
cascading. The connection to the protection device can be of operating cycles
9
either through the DIGSI Ethernet service interface Port A or at rated short-
through IEC 61850 GOOSE on Port B (System interface with circuit current
EN100 module).
breaking current
Methods for determining circuit-breaker contact wear or Commissioning
Commissioning could not be easier and is supported by
maintenance intervals to be aligned to their actual degree of
DIGSI 4. The status of the binary inputs can be read individu-
wear. The benefit lies in reduced maintenance costs.
10
There is no exact mathematical method to calculate the ally. The operation of switching elements (circuit-breakers,
wear or the remaining service life of a circuit-breaker that disconnect devices) can be checked using the switching
represented as wide-ranging operational measured values.


1
poses can be connected to a control and protection system.
Test operation
During commissioning, all indications can be passed to a
control system for test purposes.
2
10

1
Infeed Infeed
Substation 'A' Substation 'B'
2 52 52
27 50/50N 51/51N 79 27 50/50N 51/51N 79

3 Fault localization Fault localization

Load Communication network Load
jdiff jdiff
52 52
4 50/50N 51/51N 79
50/50N 51/51N 79
5 Load
Fault localization
jdiff
Fault localization
jdiff
Load
6 50/50N 51/51N 79
Current-jump detection
52
7 Disconnect ion
Fig. 9/14 Ring system application with SIPROTEC 7SC80
10

Radial systems
1
General hints: 1) Auto-reclosure
The relay at the far end (D) from the (ANSI 79) only with
Infeed
overhead lines
infeed has the shortest tripping
2) Unbalanced load
time. Relays further upstream have to protection (ANSI 46) Transformer protection
be time-graded against downstream as backup protection
2
relays in steps of about 0.3 s. against asymmetrical
faults
A 52
Busbar
3
I>t IN>t I2>t AR
51 51N 46 79
2) 1)
Busbar
* C 52
4
I>t IN>t I2>t
51 51N 46
Load
5
Busbar
D
* 52
I>t IN>t I2>t

6
51 51N 46
9_9_LSA4839-us.pdf
Load Load 7
Fig. 9/15 Protection concept with overcurrent protection
10


compensated systems 1) The sensitive current
1
Infeed
measurement of
In isolated or compensated systems, the earth current
an occurred earth fault can be should be made by a
easily found by means of sensitive zero-sequence current
transformer
directional earth-fault detection.
Busbar
2
52
I>> I>t
50 51
3 7XR96
1)
IN>t dir.
67Ns
60/1
Load
4 Fig. 9/16 Protection concept for directional earth-fault detection
Ring-main cable
5
Infeed Infeed
52
protection, 100 % of the line can be
protected via instantaneous tripping
52 52
(ring-main cable).
6
I>t IN>t υ>t I2>t
For lines with infeed from two sourc- 51 51N 49 46 Direct.Compar.Pickup
es, no selectivity can be achieved with

Overhead line Overhead line Protection as in
a simple definite time-overcurrent
9_10_LSA4841-us.pdf
protection. Therefore, the directional I>t IN>t dir. I>t IN>t
or cable 1
7
definite time-overcurrent protection 67 67N 51 51N
must be used. A non-directional
definite time-overcurrent protection
is enough only in the corresponding 52 52
busbar feeders. The grading is done 52
8
from the other end respectively.
Advantage: 100% protection of 52 52
the line via instanta-
neous tripping, and 67 67N 51 51N
easy setting. I>t IN>t dir. I>t IN>t
9 Disadvantage: Tripping times

increase towards the
Overhead line
or cable 3
Overhead line
or cable 4
Protection as in
the case of line
or cable 3
infeed. I>t IN>t dir. I>t IN>t
67 67N 51 51N
52 52
52
52 52
10 I>t
51
IN>t
51N
υ>t
49
I2>t
46
Load Load


Applicable to distribution busbars Infeed
1
I>>t0
50/50N 51/51N
2
52
t0 = 50 ms
Busbar
3
52 52 52
I>> I>t I>> I>t I>> I>t
9_11_LSA4842-us.pdf
50/50N 51/51N 50/50N 51/51N 50/50N 51/51N
4
5
solitary systems, emergency power
supply in hospitals), it may be neces-
sary to isolate selected consumers Busbar
6
from the power system in order to
protect the overall system.
V< f<
The overcurrent protection functions
7
52 27 81U
short-circuit. I>, I>>, IN>,
I>>> IN>> I>, Ip INTOC
Overloading of the generator can be 50 50N 51 51N
9_12_LSA2216a-us.pdf
8
drop. > I2> Final trip
79M 49 46 86
10

Automatic reclosing
1
The Automatic reclosing function (AR)
has starting and blocking options. In the Stage can Stage get slower executes the
opposite example, the application of the 52 be blocked than the fuse or reclosing for
lower protection the hole feeder
blocking of the high-current stages is devices graduated
2
cycles. The overcurrent protection is ON
52 52
graded (stages I, Ip) according to the TRIP
grading plan. If an Automatic reclosing I>, I>>, I>>> I>t, I>>t, Ip
9_13_LSA2219c-us.pdf
function is installed in the incoming 50 51
supply of a feeder, first of all the complete IN>t, IN>>t,
50N 51N 79
of fault. Arc faults will be extinguished
3 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 52 Fuse opens by
4
unsuccessful reclosing
a permanent fault, further reclosing
cycles will be performed. Depending on I>t, Ip
the setting of the AR, the instantaneous 67
by unsuccessful reclosing
tripping stage in the infeed is blocked in
the first, second or third cycle, i.e., now
5 the grading is effective according to the
grading plan. Depending on the fault Fig. 9/20 Auto-reclosure
6 the permanent fault will be shut down
definitively.
Reverse power protection with parallel

infeeds Infeed Infeed
7
A B
If a busbar is supplied by two parallel
infeeds and there is a fault in one of the
infeeds, the affected busbar shall be
8
52 52
9_14_LSA4116-us.pdf

67 67N 32R 67 67N 32R
devices are required, which detect a
short circuit from the busbar towards the
infeed. In this context, the directional 52
time-overcurrent protection is normally
9
52 52
can be adjusted far below rated power,
Feeder Feeder
power in case of low-current faults far
Fig. 9/21 Reverse power protection with parallel infeeds
below the load current. The reverse
power protection is implemented through
the “flexible protection functions”.
10

Synchrocheck
1
Busbar
connected, the synchrocheck
determines whether the connection V2
is permissible without danger to Closing Signal
the stability of the power system. In mm 52
2
1
the example, load is supplied from
a generator to a busbar through a
Local/remote
the transformer can be considered Transformer control
by means of a programmable angle VT1 1)
Syncro_7SC80-us ai
3
25 SYN
adjustment, so that no external 2)
adjustment elements are necessary. 79 AR
3
Infeed G
Synchrocheck can be used for
1)
functions (local or remote). Synchrocheck
2)
Automatic reclosing
Fig. 9/22 Measurement of busbar and feeder voltage for synchronization 4
5
Busbar
Protection of a transformer High-voltage
59-1 PU ,t
The high-current stage enables a
59
cur-
rent grading, the overcurrent
stages work as backup protection to
6
I>, I>> I>t, I>>t, Ip >t I2>t, I2>>t
TRIP
subordinate protection devices, and 52 50 51 49 46
the overload function protects the IN>, IN>>

IN>t, IN>>t,
INTOC
transformer from thermal overload. 50N 51N Inrush blocking
Low-current, single-phase faults

on the low-voltage side, which are
reproduced in the opposite system
on the high-voltage side, can be
52 7
detected with the unbalanced load
protection. The available inrush 87
blocking prevents pickup caused

by the inrush currents of the trans-
former.
e.g.
7UT61
52 8
*
IN>, IN>> IN>t, IN>>t, INTOC

50N 51N
52 9
Busbar
Medium-voltage
TRIP
52 52 52 52
I2>>t, I2>t I>, I>> I>t, I>>t, Ip

46 50 51
typical Feeder
10
Unbalanced fault

Description Order No. Short code
1
12345 6 7 8 9 10 11 12 13 14 15 16 17 18 19
Feeder Protection SIPROTEC 7SC80 7SC80 - -3 +
Housing, binary inputs and outputs

Housing, 12 BI, 8 BO, 1 life contact 2
2
Housing, 20 BI, 15 BO, 1 Life contact, 2 x V4) 3
Specification of CT and VT measurement inputs

3 x I LPS / LoPo, 1 x V 1) 1
4 x I 1 A / 5 A, 1 x V 2
3 x I LPS / LoPo, 4 x V 1) 3
3
4 x I 1 A/5 A, 4 x V 4
3 x I 1 A / 5A, 1 x IEE (sensitive) = 0,001 to 1,6 A / 0,005 to 8 A, 1 x V 5
3 x I 1 A / 5 A, 1 x IEE (sensitive) = 0,001 to 1,6 A / 0,005 to 8 A, 4 x V 6
4 DC 60 V to 250 V; AC 115 V; AC 230 V

DC 24 V / 48 V
1
2
DC 24 V / 48 V, Battery monitoring 3
Unit version
5 Surface mounting housing 5)

Surface / Flush mounting housing with HMI
A
B
Surface mounting housing with detached HMI C
Region-specific default and language settings 2)
6 Region DE, IEC, language German 2)

Region World, IEC / ANSI, language English 2)
A
B
Region US, ANSI, language US-English 2) C
Region World, IEC/ANSI, language French 2) D
Region World, IEC / ANSI, language Spanish 2) E
7 Region World, IEC/ ANSI, language Russian 2) G
System interface L
No port 0
100 Mbit Ethernet, electrical, RJ45 connector 9 R
8 100 Mbit Ethernet, with integrated switch, optical, 2 x LC connector multimode

100 Mbit Ethernet, with integrated switch, optical, 2 x LC connector singlemode 24 km
9
9
S
T
Protocol for system interface

IEC 61850 L 0
9 IEC 61850 + DNP3 TCP

IEC 61850 + PROFINET 3)
L 2
L 3
IEC 61850 + IEC 60870-5-104 L 4
DNP3, RS485 L 6 G
Additional interfaces
No module 0
IRIG-B optical module 6
GPS-module 7
see
10 Functionality
MLFB - number 13, 14, 15, 16 for optional features
next
page
1) The mentioned sensors of SICAM FCM can be used. For protection related purpose the usability of the sensors have to be checked
2) Language selectable
3) Only with 100 Mbit Ethernet electrical and multimode
4) Only with position 7 = 3,4 or 6
5) HMI can be ordered separately: without cable C53207-A406-D242-A / with cable C53207-A406-D243-1.

ANSI No. Description Order No. Short code
1
12345 6 7 8 9 10 11 12 13 14 15 16 17 18 19
7SC80 - -3 +
Software packages Base Package A F A

50 / 51 Time-overcurrent protection phase: I>, I>>, I>>>, Ip
2
50N / 51N Time-overcurrent protection ground IE >, IE >>, IE >>>, IEP
50N(s) / 51N(s) Sensitive ground fault protection IEE>, IEE>>, IEEp 4)
46 Negative sequence / unbalanced load protection
49 Thermal Overload protection
87N High impedance REF 3)
37 Undercurrent
3
51c Cold load pickup
81HBL2 Inrush restraint
86 Lockout
60CTS CT supervision
Jump detector with Delta measurement
Control of circuit breaker
Flexible protection functions (current parameters) 4
Under- / overfrequency
Fault recording, average values, min/max values
Sectionalizer function
Base Package B (containing A) 1) F B
67
67N
Directional overcurrent protection phase I>, I>> , I>>>, IEp
Directional overcurrent protection ground IE>, IE>>, I>>>, IEp
5
67Ns Directional sensitive ground fault protection IEE>, IEE>>, IEEp 4)
27/ 59 Under- / overvoltage
81U / O Under- / overfrequency f< ,f>
25
6
Sync-check
47 Negative-sequence overvoltage protection
60VTS VT supervision
32 / 55 / 81R Flexible protection functions (current and voltage parameters)
Protective function for voltage,
power, power factor, frequency change
Base Package N (containing R) 2) 5) FN

7
NTP-server functionality, no protection
Base Package R 2) F R
pure RTU functionality, no protection
Sectionalizer function
8
Additional functions
9
Without 0
79 With autoreclose 1
FL With fault locator 1) 2
79 / FL With autoreclose and fault locator 3
79 / TS With single/triple pole autoreclose 1) 4
79 / TS / FL With single/triple pole autoreclose and fault locator 1) 5
1) Only with position 7 = 3, 4 or 6

2) Only with position 16 = 0 10
3) 87N (REF) only with sensitive ground current input (position 7 = 5 oder 6)
epending On the ground current Input the function will be either sensitive (I EE) or Non-sensitive (I E)
4) D
5) Only with position 12 = 7

Connection diagrams
1
72 BI1 + 1
SIP.Com_002_en ai
71 BI2 + 2
70 BI3 + 3
+
2
69 BI4 4
68 BI5 + 5
67 BI6 + 6
66 BI7 + 7
65 BI8 + 8
64 IC - 9
63 10
62 IB/INs BI9 + 11
3
61 BI10 + 12
60 IA/INs BI11 + 13
59 BI12 + 14
58 - 15
57 16
56 Vx/IA BO1 17
4
55 18
54 BO2 19
53 20
52 BO3 21
51 22
50 BO4 23
5
49 24
BO5 25
48
26
46 Life contact BO6 27
28
47
BO7 29
Interference suppression capacitors at the relay

6
45 30
44 BO8 31
43 32
42
41 - contacts, ceramic, 2.2 nF, 250 V
+ BAT IN GPS/IRIG-B connection
40
(optional)
7
39
38 Port F
37 e.g. System interface
36
35 USB-DIGSI interface
- =
8
34
+ (~) Power supply
33 = HMI interface
Fig. 9/24 Connection diagram SIPROTEC 7SC8021
10

Connection diagrams
1
72 IN, INs BI1 + 1
SIP.Com_003_en ai
71 BI2 + 2
70 IC BI3 + 3
+
2
69 BI4 4
68 IB BI5 + 5
67 BI6 + 6
66 IA BI7 + 7
65 BI8 + 8
64 - 9
63 10
62 BI9 + 11
3
61 BI10 + 12
60 BI11 + 13
59 BI12 + 14
58 - 15
57 16
56 Vx BO1 17
4
55 18
54 BO2 19
53 20
52 BO3 21
51 22
50 BO4 23
5
49 24
BO5 25
48
26
28
47
BO7 29

6
45 30
44 BO8 31
43 32
42
41 - contacts, ceramic, 2.2 nF, 250 V
40
(optional)
7
39
38 Port F
36
- =
8
34
+ (~) Power supply
33 = HMI interface
Fig. 9/25 Connection diagram SIPROTEC 7SC8022 and SIPROTEC

7SC8025
10

Connection diagrams
1
72 BI1 + 1
SIP.Com_004_en ai
71 BI2 + 2
70 BI3 + 3
+
2
69 BI4 4
68 BI5 + 5
67 BI6 + 6
66 BI7 + 7
65 BI8 + 8
64 IC - 9
63 10
62 IB/INs BI9 + 11
3
61 BI10 + 12
60 IA/INs BI11 + 13
59 BI12 + 14
58 - 15
57 16
56 Vx/IA BO1 17
4
55 18
54 VC BO2 19
53 20
52 VB BO3 21
51 22
50 VA BO4 23
5
49 24
BO5 25
48
26
28
47
BO7 29

6
45 30
44 BO8 31
43 32
42
41 -
contacts, ceramic, 2.2 nF, 250 V
40
(optional)
7
39
38 Port F
36
- =
8
34
+ (~) Power supply
33 = HMI interface
10

Connection diagrams
1
72 IN, INs BI1 + 1
SIP.Com_005_en ai
71 BI2 + 2
70 IC BI3 + 3
+
2
69 BI4 4
68 IB BI5 + 5
67 BI6 + 6
66 IA BI7 + 7
65 BI8 + 8
64 - 9
63 10
62 BI9 + 11
3
61 BI10 + 12
60 BI11 + 13
59 BI12 + 14
58 - 15
57 16
56 Vx BO1 17
4
55 18
54 VC BO2 19
53 20
52 VB BO3 21
51 22
50 VA BO4 23
5
49 24
BO5 25
48
26
28
47
BO7 29

6
45 30
44 BO8 31
43 32
42
41 -
contacts, ceramic, 2.2 nF, 250 V
40
(optional)
7
39
38 Port F
36
- =
8
34
+ (~) Power supply
33 = HMI interface
Fig. 9/27 Connection diagram SIPROTEC 7SC8024 and SIPROTEC 7SC8026
10

Connection diagrams
1
72 V2B 73 BI1 + 1
71 74 BI2 + 2
70 V2C 75 BI3 + 3
2
69 76 BI4 + 4
68 77 BI5 + 5
67 78 BI6 + 6
66 79 BI7 + 7
65 - 80 BI8 + 8
BI13 + 81 - 9
64 IC BI14 + 82 10
63 BI15 + 83 BI9 + 11
+ +
3
62 I B/INs BI16 84 BI10 12
61 BI17 + 85 BI11 + 13
60 I A/INs BI18 + 86 BI12 + 14
59 BI19 + 87 - 15
58 BI20 + 88 16
57
56 Vx / V2A BO9 89 BO1 17
4 55
54 VC BO10
90
91
92
BO2
18
19
20
53
52 VB BO11 93 BO3 21
51 94 22
50 VA BO12 95 BO4 23
5
49 96 24
BO13 97 BO5 25
48 98 26
47 Life Contact BO14 99 BO6 27
46 100 28
45 BO15 101 BO7 29
6
44 102 30
43 = - BO8 31
103
Interference Suppression Capacitors at the Relay Contacts,

42 Power Supply (~) + 32
- = 104
41
+ BAT IN
40
39 GPS/IRIG-B connection
38 (optional)
7 37
36
35
Port F
34 - =
Ceramic, 2.2 nF, 250 V
+ (~) Power Supply USB-DIGSI-Interface

33 =
8
HMI-Interface
10

Connection diagrams
1
72 I N, INS V2B 73 BI1 + 1
71 74 BI2 + 2
70 IC V2C 75 BI3 + 3
2
69 76 BI4 + 4
68 IB 77 BI5 + 5
67 78 BI6 + 6
66 IA 79 BI7 + 7
65 - 80 BI8 + 8
BI13 + 81 - 9
64 BI14 + 82 10
63 BI15 + 83 BI9 + 11
+ +
3
62 BI16 84 BI10 12
61 BI17 + 85 BI11 + 13
60 BI18 + 86 BI12 + 14
59 BI19 + 87 - 15
58 BI20 + 88 16
57
56 Vx / V2A BO9 89 BO1 17
4
55 90 18
54 VC BO10 91 BO2 19
53 92 20
52 VB BO11 93 BO3 21
51 94 22
50 VA BO12 96 BO4 23
5
49 96 24
BO13 97 BO5 25
48 98 26
47 Life Contact BO14 99 BO6 27
46 100 28
45 BO15 101 BO7 29
44 102 30
6
43 31
= - 103
BO8
Interference Suppression Capacitors at the Relay Contacts,

42 Power Supply (~) + 32
- = 104
41
+ BAT IN
40
39 GPS/IRIG-B connection
38 (optional)
7
37
Port F
36
35
34 - =
Ceramic, 2.2 nF, 250 V
+ (~) Power Supply USB-DIGSI-Interface

33 =
HMI-Interface
8
Fig. 9/29 Connection diagram SIPROTEC 7SC8034 and SIPROTEC 7SC8036
10

Connection examples
and voltage transformers
1 Current transformer connections
52 52 52
anschl-3-stromwdl-sternpunktstrom
66 IA 65
68 IB 67
2 70 IC 69
P2 S2
IN
P1 S1 72 71
A B C SIPROTEC
3 Fig. 9/30 Current transformer connections to three current transform-

ers and neutral point current (ground current) (Holmgreen
connection) – appropriate for all networks
4
52 52 52
IA
5
66 65
68 IB 67
anschl-2-stromwdl-110220
70 IC 69
P2 S2
72 IN 71
P1 S1
6 A B C SIPROTEC
Fig. 9/31 Current transformer connections to two current transformers
7
– only for isolated or resonantgrounded networks
8 52 52 52
66 IA 65
IB
9
68 67
70 IC 69
P2 S2
anschl-3-stromwdl-summenstromw
IN
P1 S1 71 72
SIPROTEC
A B C
P2 S2
P1 S1
10
Fig. 9/32 Current transformer connections to three current transformers,
ground current from an additional summation current trans-
former – preferably for effectively or low-resistance grounded
networks

Connection examples
Transformer connections
A
B
C
Busbar 1
A
X
a
x
2
50 VA 49
52 VB 51
52 52 52 VC
54 53
56 Vx 55
66 IA
IB
65 3
dw_7SC80_conn-example
68 67
70 IC 69
P2 S2
4
72 IN 71
P1 S1
SIPROTEC
A B C
Fig. 9/33 Transformer connections to three current transformers
5
and three voltage transformers (phaseto-ground voltages),
normal circuit layout – appropriate for all networks
6
A B C
A X a x VA
50 49
7
52 VB 51
54 VC 53
56 Vx / V2A 55
52 52 52 Circuit bre ake r/Recloser
dw_7SC803_conn-example_6PT 8
A X a x
74 V2B 73
76 V2C 75
SIPROTEC
9
A B C
Fig. 9/34 Transformer connections to three current transformers and

six voltage transformers (phase-toground voltages), normal
circuit layout – appropriate for all networks
10

Connection examples
Voltage transformer connections
1 A
B Busbar
C
A
2
X
e
n
a
52 52 52 x
3 50 VA-B 49
dw_Vab-Vbc-Vn connection
52 VC-B 51
54 VN 53
4 A B C
56 Vx 55
SIPROTEC
5 Fig. 9/35 Voltage transformer connections to two voltage transformers

(phase-to-phase voltages) and broken delta winding (e-n) –
6 Voltage transformer connections

for two voltage transformers in
open delta voltage connection. In
this connection, determination of
7 zero-sequence voltage V0 is not pos-
sible. Functions using zero sequence A
voltage must be disabled. B
C
A X A X
8 a x a x
52 52 52
50 VA-B 49
VC-B
9
52 51
54 VN 53
dw_Vab-Vbc connection
A B C Vx
56 55
SIPROTEC
Fig. 9/36 Voltage transformer connections for two voltage transformers in open

delta voltage connection.
10

Connection examples
1
A X e n a x
50 VA-B 49
52 VC-B
VN
51 2
54 53
52 52 52 Circuit breaker/Recloser
A X e n a x
3
dw_7SC803_conn-example-Vab-Vbc-Vn
V2A-V2B
4
56 55
74 V2C-V2B 73
VNS2
76 75
SIPROTEC
5
A B C
Fig. 9/37 Voltage transformer connections to two voltage transformers

(phase-to-phase voltages) and broken delta winding (e-n) –
6
for two voltage transformers in A a
open delta voltage connection. In

this connection, determination of
X
A
x
a 7
zero-sequence voltage V0 is not pos- X x
50
VA-B
49
sible. Functions using zero sequence VC-B
52 51
voltage must be disabled.
VN
8
54 53
52 52 52 Circuit bre ake r/Recloser
SIPROTEC
A a
X x
9
A a
X x
56 V2A-V2B 55
74 V2C-V2B 73
dw_7SC803_conn-example-Vab-Vbc
76 VNS2 75
A B C
SIPROTEC
10
Fig. 9/38 Voltage transformer connections for two voltage transformers
in open delta voltage connection

Connection examples
Transformer connections
A
1
B Busbar
C
[anschl-3-stromwdl-3-spgwdl-kapazitiv
2
50 VA 49
52 VB 51
54 VC 53
56 Vx 55
52 52 52
66 IA 65
IB
3
68 67
70 IC 69
P2 S2
72 IN 71
P1 S1
A B C SIPROTEC
4
Fig. 9/39 Transformer connections to three current transformers and
three voltage transformers –capacitive
6
A B C
7 50
52
VA
VB
49
51
54 VC 53
56 Vx / V2A 55
8 52 52 52 Circuit bre ake r/Recloser

dw_7SC803_conn-example_6PT_capacitive
9
74 V2B 73
76 V2C 75
SIPROTEC
A B C
Fig. 9/40 Transformer connections to three current transformers and six

10 voltage transformers – capacitive

Connection examples
52 52 52 64
63 IC 1
62
61 IB
60
59 IA 2
* * *
SIP.Com_012_en ai
SIPROTEC
3
A B C
Fig. 9/41 Standard connection 3 phase currents via LoPo/LPS
9
You will find a detailed overview of the
technical data in the current manual
10

Connection types
1
(Low-resistance) grounded Time-overcurrent protection Residual circuit, with 3 phase- –
networks phase/ground non-directional current transformers required,
2 networks
(Low-resistance) grounded Directional time-overcurrent Residual circuit, with 3 phase- Phase-to-ground connection or
Isolated or compensated Directional time- overcurrent Residual circuit, with 3 or 2 phase- Phase-to-ground connection or
3
(Low-resistance) grounded Directional time-overcurrent Residual circuit, with 3 phase- Phase-to-ground connection
networks protection, ground-faults current transformers required, required
4
> 0.05 IN on secondary side, connection or phase-to-ground
otherwise phase-balance neutral connection with broken delta
5
winding
10

SNTP-Master/Server SIPROTEC 7SC80
Description
The hardware variant of the SIPROTEC 7SC80 integrates an

SNTP server and a GPS module.
With it the first substation hardened SNTP server with GPS
receiver is available for precise time synchronization for all
1
SIPROTEC protection devices and all other SNTP-capable
devices. Protection functions are not provided. The few
2
configuration settings (e.g. IP-address) will be done with
DIGSI 4.
The communication redundancy protocols RSTP/PRP/
HSR and IEC 61850 are supported completely. With these
SIP-COM-05.tif
features the SNTP Server with optical interfaces can be
operated directly as part of SIPROTEC ring networks.
3
A GPS antenna kit with antenna, mounting and 25 m cable
is available separately.
Function overview
• GPS-antenna interface (SMB-connector)
• USB-Port for configuration with DIGSI 4
• Default equipped with 2 electrical Ethernet ports RJ45
4
Fig. 9/36 SNTP-Master/Server 7SC80
• Dual armed connection in Active-Standby configuration
• Equipped with 2 optical Ethernet interfaces (optional)
Applications
5
• Detached operation possible, with single-mode inter-
faces up to 24 km With the 7SC80 SNTP time server all Ethernet attached
• Complete support of redundant ring structures with devices can be synchronized via SNTP protocol (Simple
RSTP/PRP/HSR Protocol Network Time Protocol) at a millisecond accuracy base.
• Fulfills EMC requirements in substations The transmitted time is standardized UTC-time or local time.
• Extended temperature range -50 °C - +85 °C
• Robust against heavy GOOSE load in IEC 61850 networks
For this application all (protection) devices need a suitable
Ethernet interface, e.g. in SIPROTEC 4 port B (EN100
6
module) is needed.
• Can be used as central data concentrator, e.g. recording
of GOOSE messages The GPS antenna is mounted to an outside wall or flat roof
with line of sight to the sky (order separately).
• Supports IEC 61850 Edition1 and Edition 2
• Integration in IEC 61850 substation controller
The SNTP server will be mounted close to the antenna and 7
(with max. 6 Clients) will be typically supplied with the same auxiliary voltage
as the protective relays. By using the optical interfaces,
• Integration in DIGSI 4 IEC 61850 system configurator
any EMC influence is excluded, even with long distances
• Additional deployment for automation (CFC)
8
between SNTP Server and protective relays.
• Remote Access By using the 7SC80 for time synchronization the typical
• Optimized for use together with SIPROTEC devices and accuracy is ±1 ms. A dedicated network for time synchroni-
EA-Products zation is not necessary.
• In accordance with SIPROTEC protective relays. The deployment of 7SC80 in redundant SNTP time server
scenarios is possible as well. The integration in DIGSI-
projects can be done with the complete 7SC80 parameter
9
set; the usage of SNTP.ICD files is no longer necessary.
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

SNTP-Master/Server SIPROTEC 7SC80
1
Sub station automatio n
tech nology
GPS an ten na GPS an ten na
2
Etherne t switch
SNTP SNTP
7SC802 7SC802
3 RSTP/HSR ring
SIPROTEC SIPROTEC
Device Device
SI EMENS
SI EMENS
4
SIPROTEC SIPROTEC
Device Device
SI EMENS SI EMENS
dw_example_ring
5 Fig. 9/37 Example of a redundant integration of a 7SC80 SNTP server in an optical SIPROTEC ring network
6 Selection and ordering data
Description Order No. Short Code

12345 6 7 8 9 10 12 13 14 15 16 17 18 19
SNTP-Master / Server 7SC80 7SC80 2 1 - B 9 7 - 3 F N O- L
7
DC 60 V to 250 V; AC 115 V; AC 230 V 1
DC 24 V / 48 V 2
8 Unit Version
Surface mounting housing A
Surface / Flush mounting housing with HMI B
Surface mounting housing with detached HMI C
9 System Interface
100 Mbit Ethernet, electrical, 2 x RJ45 connector 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
IEC 61850 0
IEC 61850 + DNP3 TCP 2
IEC 61850 + PROFINET IO 3
IEC 61850 + IEC 60870-5-104 4
10 GPS antenna kit 7XV56 6 3 - 0 A A 0 0
Indirect lightning protection 7XV56 6 4 - 0 L A 0 0

Attachment
SIPROTEC Compact
Attachment
Page
1
Ordering examples and accessories 10/3
2 Dimension drawings 10/5
Legal notice 10/7
10

Attachment
Ordering examples and accessories
Ordering example
Position Description Order No. Short code
12 3 45 6 7 8 9 10 11 12 13 14 15 16
7RW80 2 0 - 5 E C 9 6 - 1 D A 0 + L 0 G
1
6 Housing 1/6 19", 3xV, 7 BI, 8 BO1), 1 life contact 2
8
9
Rated auxiliary voltage: DC 60 V to 250 V; AC 115 V; AC 230 V
Flush mounting housing, screw-type terminal
5
E
2
10 Region US, language US-English, US front, ANSI C
11 Communication: System interface: DNP 3.0, electrical RS485 9 L 0G
12 Communication: With Ethernet interface (DIGSI, not IEC 61850), RJ45 connector 6
13 Measuring / fault recording 1
14 / 15 Protection function: Voltage and frequency relay DA
3
1) 2 changeover/Form C.
Accessories
4
Product description Variants Order No.
DIGSI 4 Basis 7XS5400-0AA00
Software for projecting and usage of all Basic version with license for 10 computers
Siemens protection devices is running under
32 bit and 64 bit
(authorisation by serial number) 5
Professional 7XS5402-0AA00
MS Windows 7 Ultimate, Enterprise and DIGSI 4 Basis
Professional, + SIGRA (Fault record analysis)
MS Windows Server 2008/R2 + CFC-Editor (Logic-Editor)
+ Display-Editor (Editor for control displays)
+ DIGSI 4 Remote (Remote operation) with license for 6
10 computers (authorisation by serial number)
Professional + IEC 61850 7XS5403-0AA00
Professional version and IEC 61850
7
System configurator
with license for 10 computers
(authorisation by serical number)
Terminals
Voltage terminal block C or block E C53207-A406-D181-1
Voltage terminal block D (inverse printed) C53207-A406-D182-1
Current terminal block 4 x I
Current terminal block 3 x I, 1 x I Nx (sensitive)
C53207-A406-D185-1
C53207-A406-D186-1
8
Current terminal short circuit links, 3 pieces C53207-A406-D193-1
Voltage terminal short circuit links, 6 pieces C53207-A406-D194-1
9
Standard USB cable (Type A-Type B) available in specialist stores
10

Attachment
Description Order No.
1
SIGRA
Software for graphic visualisation, analysis and evaluation of fault and measurement records.
See product information for supported operating systems.
Incl. templates, online manual and service (update, hotline)
Operating languages:
German, English, French, Spanish, Italian, Chinese, Russian, Turkish
2 SIGRA 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 Scientific
Installation without DIGSI 4 only for university-level institutions with license for 10 PCs
3 (authorisation by serial number) 7XS5416-1AA00
Stand Alone Version

Installation without DIGSI 4 with license for 10 PCs (authorisation by serial number) 7XS5416-0AA00
4 SIGRA Trial
Like SIGRA Stand Alone, but only valid for 30 days (test version) 7XS5411-1AA00
(no authorisation required)
5 Upgrade SIGRA Trial to SIGRA Stand Alone

Like SIGRA Stand Alone. For customers who want to unlock their trial version. 7XS5416-2AA00
With license for 10 PCs
10

Attachment
Dimension drawings
74/2.9
70/2.76
74/2.9
70/2.76
74/2.9
70/2.76
1
SIP C-0019-de.ai
LSA4837a-de.ai
3
Rear view Rear view Rear view Side view Front view Panel cut-out
7RW80 7SJ80, 7SK80 7SJ81, 7SK81
and 7SD80
4
Fig. 10/1 Panel surface and cabinet flush mounting
9
165,1
LSA4834a-de.ai
192,6
199,1
29,7 251,5
Side view 7RW80 Side view 7SJ8, 7SK8, 7SD80 Front view
Fig.10/2 Side views for panel surface mounting

10

Attachment
Dimension drawings
2±0.5 (0.08±0.02)
1
7SC80
SI EMEN S
2
1 17 7SC80
2 18 RUN
3 19 ERROR
4 20 Battery
5 21
6 22
7 23 Esc Ent er
8 24
9 25
10 26
11 27
1 6
307 (12.09)
12 28
13 29
2 7
3
14 30
15 31
16 32 3 8
Op en ed Cl ose d
Op en Clo se 4 9
Op en ed Cl ose d
Op en Clo se 5 0
Op en ed Cl ose d
Op en Clo se Nu m
Lo ck
4 Lo ck
PB
5 28.1 (1.11)
261 (10.28) 12.7 (0.47)
Dimensions in mm, values
6
in brackets in inches
68 (2.68)
23.8 (0.94)
103.35 (4.07)
7
Fig.10/3 7SC80 Variant with Attached HMI
10

Attachment
Dimension drawings
1
201.66 (7.94)
23.3 (0.92)
2
SI EMEN S
1 17 7SC80
2 18 RUN
3 19 ERROR
4 20 Battery
5 21
6 22
7 23 Esc Ent er
3
8 24
9 25
10 26
271.86 (10.19)
11 27
1 6
12 28
13 29
14 30
2 7
15 31
16 32 3 8
Op en ed Cl ose d
Op en Clo se 4 9
4
Op en ed Cl ose d
Op en Clo se 5 0
Op en ed Cl ose d
Op en Clo se Nu m
Lo ck
Lo ck
PB
27.8 (1.09)
35.35
(1.39)
5
Dimensions in mm,
values in brackets in
inches
6
7
Fig.10/4 7SC80 Panel with Detached HMI
10

Attachment
Notes
10

Attachment
Legal notice
Indication of conformity Copyright
This product complies with the directive of Copyright © Siemens AG 2020. All rights reserved.
the Council of the European Communities
on harmonization of the laws of the
The disclosure, duplication, distribution and editing of this 1
Member States concerning electromagnetic document, or utilization and communication of the content are
compatibility (EMC Directive 2014/30/EU), not permitted, unless authorized in writing. All rights, including
restriction on usage of hazardous substances rights created by patent grant or registration of a utility model
in electrical and electronic equipment (RoHS Directive 2011/65/ or a design, are reserved.
EU), and electrical equipment for use within specified voltage
limits (Low Voltage Directive 2014/35/EU). Trademarks
2
This conformity has been proved by tests performed according SIPROTEC, DIGSI, SIGRA, SIGUARD, SIMEAS SAFIR, SICAM, and
to the Council Directive in accordance with the product MindSphere are trademarks of Siemens. Any unauthorized use
standard EN 60255-26 (for EMC directive), the standard EN is prohibited.
50581 (for RoHS directive), and with the product standard EN
60255-27 (for Low Voltage Directive) by Siemens.
The device is designed and manufactured for application in an

3
industrial environment.
The product conforms with the international standards of

IEC 60255 and the German standard VDE 0435.
Disclaimer of Liability
4
Subject to changes and errors. The information given in this
document only contains general descriptions and/or perfor-
mance features which may not always specifically reflect those
described, or which may undergo modification in the course of
further development of the products. The requested perfor-
5
mance features are binding only when they are expressly
agreed upon in the concluded contract.
Document version: 05
Release status: 12.2020
6
10

Publisched by For all products using security features of OpenSSL the
following shall apply:
Siemens AG 2020
This product includes software developed by the
OpenSSL Project for use in the OpenSSL Toolkit.
Smart Infrastructure (http://www.openssl.org)
This product includes cryptographic software written
Digital Grid
by Eric Young (eay@cryptsoft.com )
Automation Products This product includes software written
Humboldtstr. 59 by Tim Hudson (tjh@cryptsoft.com)
This product includes software developed
90459 Nuremberg, Germany
by Bodo Moeller.
www.siemens.com/siprotec
Our Customer Support Center

provides a 24-hour service.
Siemens AG
Smart Infrastructure – Digital Grid
Customer Support Center
E-Mail: energy.automation@siemens.com
Article No. SIDG-C10064-00-7600

Ca 122020_pdf_EN

Siprotec Compact Catalog en

Uploaded by

Copyright:

Available Formats

Siprotec Compact Catalog en

Uploaded by

Document Information

Original Title

Copyright

Available Formats

Share this document

Share or Embed Document

Sharing Options

Did you find this document useful?

Is this content inappropriate?

Copyright:

Available Formats

Siprotec Compact Catalog en

Uploaded by

Copyright:

Available Formats

SIPROTEC Compact

Perfect Protection – smallest space

Manuals Manuals Manuals

Manuals Manuals Manuals Manuals

Fig. 1/1 Overview of Siemens protection catalogs

SIPROTEC Compact catalog SICAM Power Quality and Measurement catalog

SIPROTEC Compact Introduction Page

7SD80, 7SJ80, 7SJ81,

7SC80 Selection table, system features,

Ordering examples and accessories 10/3

SIPROTEC Compact · SIEMENS SIP 3.01 · Edition 5 1/3

We are pleased to have the opportunity to introduce our

At the beginning, please orientate yourself by means of a

5 Please convince yourself of the performance of SIPROTEC

1/4 SIPROTEC Compact · SIEMENS SIP 3.01 · Edition 5

Solutions for today‘s and future power supply systems –

SIPROTEC has established itself on the energy market for 1

Fig. 1/5 SIPROTEC – Pioneer over generations

SIPROTEC Compact · SIEMENS SIP 3.01 · Edition 5 1/5

SIPROTEC 5 – the new benchmark for protection,

and extensive operational equipment data are part of the

5 system operator‘s equipment and employees

• Integrated switch for low-cost and redundant optical and

Fig. 1/8 Application in a high-voltage power system

1/6 SIPROTEC Compact · SIEMENS SIP 3.01 · Edition 5

Fig. 1/11 Feeder Protection SIPROTEC 7SC80 with HMI

SIPROTEC Compact · SIEMENS SIP 3.01 · Edition 5 1/7

SIPROTEC 4 – the proven, reliable and future-proof

2 the SIPROTEC 4 device family has gained the highest ap-

4 tasks of the secondary systems can be performed with one

SIPROTEC 4 has been ensured for the entire device series

6 • Targeted and easy operation of devices and software

Fig. 1/14 SIPROTEC 4 application in power stations

1/8 SIPROTEC Compact · SIEMENS SIP 3.01 · Edition 5

SIPROTEC Compact · SIEMENS SIP 3.01 · Edition 5 1/9

1/10 SIPROTEC Compact · SIEMENS SIP 3.01 · Edition 5

SIPROTEC Compact system features 2/5

Construction and hardware 2/8

Control and automation functions 2/9

Operating programs DIGSI 4 and SIGRA 4 2/10

2/2 SIPROTEC Compact · SIEMENS SIP 3.01 · Edition 5

Further functions see next page

SIPROTEC Compact · SIEMENS SIP 3.01 · Edition 5 2/3

4 No. Setting groups

Easy Protection Device Selector

5 Table 2/1 SIPROTEC Compact relay selection table

2/4 SIPROTEC Compact · SIEMENS SIP 3.01 · Edition 5

Cable Generation Transformer Feeder Motor Bus Coupler 10

Fig. 2/1 Fields of application in a typical MV system

SIPROTEC Compact · SIEMENS SIP 3.01 · Edition 5 2/5

Feeder Protection SIPROTEC 7SC80 Load balancing

2 Detect and locate a fault in the feeder, isolate the faulty

3 sections of the feeder back into service

Fig. 2/2 Fields of application with feeder protection SIPROTEC 7SC80

2/6 SIPROTEC Compact · SIEMENS SIP 3.01 · Edition 5

In an illuminated 6-line LC display, process and

8 freely programmable LEDs serve for indication 3

USB user interface (type B) for modern

Keys “O” and “I” for direct control of

Fig. 1/11 Feeder Protection SIPROTEC 7SC80 with HMI

Fig. 2/21 Optical Ethernet communication module for IEC 61850

Port B Port A Fig. 2/24

10 Fig. 2/23 Connection of an RTD box to 7SK80