63230-216-230B1 Sepam Series 80 Reference Manual
63230-216-230B1 Sepam Series 80 Reference Manual
63230-216-230B1 Sepam Series 80 Reference Manual
Sepam Series 80
Protective Relays
Reference Manual
Instruction Bulletin
63230-216-230B1
63230-216-230-B1.book Page 2 Monday, August 6, 2007 10:35 AM
63230-216-230-B1.book Page 3 Monday, August 6, 2007 10:35 AM
Safety Instructions 0
Safety Alert
This is the safety alert symbol. It is used to alert you to potential personal injury
hazards and prompt you to consult the manual. Obey all safety instructions that
follow this symbol in the manual to avoid possible injury or death.
Safety Messages
DANGER
DANGER indicates an imminently hazardous situation which, if not avoided,
will result in death, serious injury or property damage.
WARNING
WARNING indicates a potentially hazardous situation which, if not avoided,
could result in death, serious injury or property damage.
CAUTION
CAUTION indicates a potentially hazardous situation which, if not avoided,
minor or moderate injury or property damage.
Important Notes
Restricted Liability
Electrical equipment should be serviced and maintained only by qualified personnel.
No responsibility is assumed by Schneider Electric for any consequences arising out
of the use of this manual. This document is not intended as an instruction manual for
untrained persons.
Device Operation
The user is responsible for checking that the rated characteristics of the device are
suitable for its application. The user is responsible for reading and following the
devices operating and installation instructions before attempting to commission or
maintain it. Failure to follow these instructions can affect device operation and
constitute a hazard for people and property.
Protective Grounding
The user is responsible for compliance with all the existing international and national
electrical codes concerning protective grounding of any device.
FCC Notice
This equipment has been tested and found to comply with the limits for a Class A
digital device, pursuant to part 15 of the FCC Rules. These limits are designed to
provide reasonable protection against harmful interference when the equipment is
operated in a commercial environment. This equipment generates, uses, and can
radiate radio frequency energy and, if not installed and used in accordance with the
instruction manual, may cause harmful interference to radio communications.
Operation of this equipment in a residential area is likely to cause harmful
interference in which case the user will be required to correct the interference at his
own expense. This Class A digital apparatus complies with Canadian ICES-003.
Schneider Electric Electric. All Rights Reserved.
2007 Schneider 63230-216-230B1 63230-216-230-
B1_0_frontcover.fm/3
63230-216-230-B1.book Page 4 Monday, August 6, 2007 10:35 AM
63230-216-230-B1.book Page i Monday, August 6, 2007 10:35 AM
Contents
Introduction 1
Metering Functions
2
Protection Functions
3
Appendix
A
Introduction Contents
PE50465
DE51730
increasing levels of performance: b 8 relay outputs N.O.
b 1 communication port
b Sepam Series 20, for simple b 8 temperature sensor
applications inputs
b Sepam Series 40, for demanding
applications
DE51731
N.O.
DE51732
reference 63230-216-238 b 8 relay outputs N.O.
DE51733
b Sepam Series 80 Operation Manual, b 23 relay outputs N.O.
b Logic equation editor
reference 63230-216-229 b 2 communication ports
b Sepam DNP3 Communication Users for multimaster or
Manual, redundant architecture
reference 63230-216-236 b 16 temperature sensor
inputs
b Sepam IEC 60870-5-103 b Removable memory
Communication Users Manual,
PE50464
DE51734
N.O.
DE51736
Protection Applications
Standard Specific Substation Bus Transformer Motor Generator Capacitor
1
Current protection Breaker failure S23 T23 M20
Disconnection B22
(ROCOF)
Introduction Presentation
The Sepam range of protection relays is Sepam Series 80: Intelligent Solutions for
designed for operating machines, the
1 electrical distribution networks of industrial
installations, and utility substations at all
Custom Applications
Specially designed for demanding customers on large industrial sites, Sepam
Series 80 provides proven solutions for electrical distribution and machine protection
levels of voltage. The Sepam family
includes:
b Sepam Series 20
Main Characteristics
The Sepam Series 80 offers these features:
b Sepam Series 40 b protects closed ring networks or networks with parallel mains by means of
b Sepam Series 80 directional protection and zone selective interlocking
to cover all needs, from the simplest to the b directional ground fault protection for impedance-grounded and effectively
most complete. ungrounded or compensated neutral systems (designed to compensate for
system capacitance using a tuned inductor in the neutral. This is not common in
North America).
b complete protection of transformers and machine-transformer units
v stable, sensitive differential protection with neural network restraint
v linked to all necessary backup protection functions
PE50278
Selection Guide
The Sepam Series 80 family includes 16 types to offer the right solution for each
application.
PE50286
b integrated mimic-based UMI
b integrated or remote advanced UMI
7 Sync-check module
8 Software tools:
b Sepam parameter and protection setting, and
predefined control functions adaptation
b local or remote installation operation
b programming specific functions (Logipam)
b retrieval and display of disturbance recording
data
Easy Installation
b light, compact base unit
b easy to integrate due to Sepams adaptation capabilities:
v universal supply voltage and logic inputs: 24 to 250 V DC
v phase currents may be measured by 1A or 5A current transformers, or LPCT
(Low Power Current Transducer) type CTs
v residual current calculated or measured by a choice of methods to fit
requirements
b the same, easy-to-install remote modules for all Sepam units:
v mounted on DIN rail
v connected to the Sepam base unit by prefabricated cords
Commissioning Assistance
b predefined functions implemented by simple parameter setting
b user-friendly, powerful SFT2841 PC setting software tool used on all Sepam
units to provide users with all the possibilities offered by Sepam.
Intuitive Use
b integrated or remote advanced User Machine Interface (UMI) installed in the
most convenient place for the facility manager
b integrated mimic-based User Machine Interface for local control of switchgear
b user-friendly User Machine Interface, with direct access to data
b clear graphic LCD display of all data required for local operation and installation
diagnosis
b working language may be customized to be understood by all users
Note : * Modbus, IEC60870-5-103, or DNP3 are available using ACE9492, ACE 959, ACE937, ACE969TP or ACE969FO.
Weight
Base Unit with Advanced UMI Base Unit with Mimic-Based UMI
1 Minimum weight (base unit without MES120)
Maximum weight (base unit with 3 MES120)
5.29 lb. (2.4 kg)
8.82 lb. (4.0 kg)
6.61 lb. (3.0 kg)
10.1 lb. (4.6 kg)
Instrument Transformer Inputs
Phase Current Inputs 1A or 5A CT
Input impedance < 0.02
Burden < 0.02 VA (1A CT)
< 0.5 VA (5A CT)
Continuous thermal withstand 4 In
1 second overload 100 In
Voltage Inputs Phase Residual
Input impedance > 100 k > 100 k
Burden < 0.015 VA (100 V VT) < 0.015 VA (100 V VT)
Continuous thermal withstand 240 V 240 V
1-second overload 480 V 480 V
Isolation of inputs from other Enhanced Enhanced
isolated groups
Relay Outputs
Control Relay Outputs O1 to O4 and Ox01 (1)
Voltage DC 24/48 V DC 125 V DC 250 V DC
AC (47.5 to 63 Hz) 100 to 240 V AC
Continuous current 8A 8A 8A 8A
Breaking capacity Resistive load 8A/4A 0.7 A 0.3 A
Load L/R < 20 ms 6A/2A 0.5 A 0.2 A
Load L/R < 40 ms 4A/1A 0.2 A 0.1 A
Resistive load 8A
Load p.f. > 0.3 5A
Making capacity < 15 A for 200 ms
Isolation of outputs from other Enhanced
isolated groups
Annunciation Relay Outputs O5 and Ox02 to Ox06
Voltage DC 24/48 V DC 127 V DC 220 V DC
AC (47.5 to 63 Hz) 100 to 240 V AC
Continuous current 2A 2A 2A 2A
Sepam Series 80 has analog inputs that are connected to the measurement
instrument transformers required for applications:
DE50583
The table below lists the analog inputs available according to the type of
MET2 Sepam Series 80.
Phase-to-neutral voltage
Main channels (V)
Additional channels (V)
Main channels (Van, Vbn, Vcn)
0.05 to 1.2 V(L-L)p
0.05 to 1.2V(L-L)p
0.05 to 1.2 V(L-n)p
0.5 %
1 %
0.5 % b
Additional channels (Van, Vbn, Vcn) 0.05 to 1.2 V(L-n)p 1 %
Residual voltage 0.015 to 3 V(L-n)p 1 %
Neutral point voltage 0.015 to 3 Vntp 1 %
Positive sequence voltage 0.05 to 1.2 Vnp 2 %
Negative sequence voltage 0.05 to 1.2 Vnp 2 %
Frequency Main channels (f) 25 to 65 Hz 0.01 Hz b
Additional channels (f) 45 to 55 Hz (fn = 50 Hz) 0.05 Hz
55 to 65 Hz (fn = 60 Hz)
Active power (total or per 0.008 Sn to 999 MW 1 % b
phase)
Reactive power (total or per phase) 0.008 Sn to 999 MVAR 1 % b
Apparent power (total or per phase) 0.008 Sn to 999 MVA 1 % b
Peak demand active power 0.008 Sn to 999 MW 1 % v
Peak demand reactive power 0.008 Sn to 999 MVAR 1 % v
Power factor 1 to + 1 (CAP/IND) 0.01 b
Calculated active energy 0 to 2.1 x 108 MWh 1 % 1 digit v v
Calculated reactive energy 0 to 2.1 x 108 MVARh 1 % 1 digit v v
Temperature 30 C to +200 C 1 C from +20 b
or 22 F to +392 F to +140 C
Rotation speed 0 to 7200 rpm 1 rpm
Network Diagnosis Assistance
Tripping context v
Tripping current 0.02 to 40 IN 5 % v
Number of trips 0 to 65535 - v v
Negative sequence / unbalance 1 to 500 % of IB 2 %
Total harmonic distortion, current 0 to 100 % 1 %
Total harmonic distortion, voltage 0 to 100 % 1 %
Phase displacement r (between Vr and Ir) 0 to 359 2
Phase displacement a, b, c (between V and I) 0 to 359 2
Disturbance recording v
Amplitude difference 0 to 1.2 VLLsync1 1 %
Frequency difference 0 to 10 Hz 0.5 Hz
Phase difference 0 to 359 2
Out-of-sync context v
b available on MSA141 analog output module, according to setup
v v saved in the event of auxiliary supply outage, even without battery
v saved by battery in the event of auxiliary supply outage
(1) Typical accuracy, see details on subsequent pages
Sepam processes each measured signal to produce all the values necessary for
The charts below identify (according to the various functions) the values produced
from the signals measured, with:
b RMS = RMS value up to the 13th harmonic
b H1 = fundamental 50 Hz or 60 Hz component
b H1 = vector sum of the fundamental components of the three phases
b H3 = 3rd harmonic component
b H3 = vector sum of the 3rd harmonic components of the three phases.
The phase rotation direction should be set for correct calculation of the symmetrical
components (Va, Vb, Vr, Ia, Ib, Ir).
Phase Current
Operation
This function provides an RMS value for the phase currents:
b Ia: phase a current, main channels
b Ib: phase b current, main channels
b Ic: phase c current, main channels
b Ia: phase a current, additional channels
b Ib: phase b current, additional channels
2 b Ic: phase c current, additional channels
It is based on RMS current measurement and considers up to the13th harmonic.
Different types of current transformers (CTs) can monitor phase current:
b 1A or 5A current transformers
b Low Power Current Transducer (LPCT) type current sensors
Readout
Access to the measurements is by one of the following:
b Sepam display via the key
b a PC loaded with SFT2841 software
b a communication link
b an analog converter with the MSA141 option
Characteristics
Measurement range 0.02 to 40 IN (1)
Units A or kA
Resolution 0.1 A
Accuracy 0.5 % typical (2)
1 % from 0.3 to 1.5 IN
2 % from 0.1 to 0.3 IN
Display format 3 significant digits
Refresh interval 1 second (typical)
(1) In rated current set in the general settings
(2) At In, under reference conditions (IEC 60255-6)
Residual Current
Operation
This operation provides an RMS value of the residual current. It is based on
measuring the fundamental component. Four types of residual current values are
available, depending on the type of Sepam and CTs connected:
b two residual currents, Ir and I'r, which are calculated by the vectoral sum of
the three phase currents
b two measured residual currents, Ir and I'r
Different types of CTs can be used to measure residual current:
b CSH120 or CSH200 specific zero sequence CT
b conventional 1A or 5A current transformer
b any zero sequence CT with an ACE990 interface.
Readout
Access to the measurements is by one of the following:
b a Sepam display via the key
b a PC with SFT2841 software
b a communication link
b an analog converter with the MSA141 option.
Characteristics
Measurement range Ir or Ir 0.005 to 40 IN (1)
Ir or Ir measured by CSH zero sequence CT Rating INr = 2 A 0.005 to 20 INr (1)
INr = 20 A 0.005 to 20 INr (1)
Ir or Ir measured by zero sequence CT with ACE990 0.005 to 20 INr (1)
Ir or Ir measured by CT 0.005 to 20 INr (1)
Units A or kA
Resolution 0.1 A or 1 digit
Accuracy (2) 1 % typical at In0
2 % from 0.3 to 1.5 INr
5 % from 0.1 to 0.3 INr
Display format 3 significant digits
Refresh interval 1 second (typical)
(1) IN, INr: nominal rating set in the general settings.
(2) Under reference conditions (IEC 60255-6), excluding CT accuracy.
Operation
Demand current and peak demand currents are calculated according to the three
phase currents Ia, Ib, and Ic:
b demand current is calculated over an adjustable period, usually 5 to 60
minutes
b peak demand current is the greatest demand current and indicates the current
drawn by peak loads
Peak demand current values can be cleared. They are saved in the event of power
loss.
Readout
2
Access the measurements by any of the following:
b the Sepam display via the key
b a PC with SFT2841 software
b a communication link.
Resetting to Zero
The user can access zero reset:
b via the clear button on the Sepam display if a peak demand is displayed
b via the clear command in the SFT2841 software
b via the communication link (remote control command TC4)
Characteristics
Measurement range 0.02 to 40 IN (1)
Units A or kA
Resolution 0.1 A
Accuracy 0.5 % typical (2)
1 % from 0.3 to 1.5 IN
2 % from 0.1 to 0.3 IN
Display format 3 significant digits
Integration period 5, 10, 15, 30, 60 min
(1) IN rated current set in the general settings.
(2) At IN, under reference conditions (IEC 60255-6).
Operation
This function gives the RMS value of the fundamental 50 Hz or 60 Hz component of:
DE50334
Readout
Access to the measurements is by one of the following:
b the Sepam display via the key
b a PC with SFT2841 software
b communication link
a-c-b network: phase-to-neutral and phase-to-phase voltages
b an analog converter with the MSA141 option
Characteristics
Measurement range 0.05 to 1.2 VLLp (1)
Units V or kV
Resolution 1V
Accuracy 0.5 % typical (2) main channels
1 % typical (2) additional channels
1 % from 0.5 to 1.2 VLLp
2 % from 0.06 to 0.5 VLLp
Display format 3 significant digits
Refresh interval 1 second (typical)
(1) Set in the general settings
(2) At VLLp, under reference conditions (IEC 60255-6)
Operation
This function gives the RMS value of the fundamental 50 Hz or 60 Hz component of:
b the main phase-to-neutral voltages Van, Vbn, and Vcn, measured on phases
a, b, and c
b the additional phase-to-neutral voltages V'an, V'bn, and V'cn, measured on
phases a, b, and c
Readout
Access to the measurements is by one of the following:
b the Sepam display via the key 2
b a PC with SFT2841 software
b the communication link
b an analog converter with the MSA141 option
Characteristics
Measurement Range 0.05 to 1.2 V(L-n)p (1)
Units V or kV
Resolution 1V
Accuracy 0.5 % typical (2) main channels
1 % typical (2) additional channels
1 % from 0.5 to 1.2 VLnp
2 % from 0.06 to 0.5 VLnp
Display Format 3 significant digits
Refresh Interval 1 second (typical)
(1) V(L-n)p: primary rated phase-to-neutral voltage (V(L-n)p = VLLp/3)
(2) At VLnp, under reference conditions (IEC 60255-6)
Residual Voltage
Operation
This function provides the following values:
Characteristics
Measurement Range 0.015 to 3 V(L-n)p (1)
Units V or kV
Resolution 1V
Accuracy 1 % from 0.5 to 3 V(L-L)p
2 % from 0.05 to 0.5 V(L-L)p
5 % from 0.02 to 0.05 V(L-L)p
Display Format 3 significant digits
Refresh Interval 1 second (typical)
(1) VLnp: primary rated phase-to-neutral voltage (VLnp = V(L-n)p/3)
Vnt = ( V an + V bn + V cn' ) 3
Readout
Access the measurements through:
b the Sepam display via the key
b a PC with SFT2841 software
b the communication link
Characteristics
Measurement Range 0.015 to 3 VLnp (1)
Units V or kV
Resolution 1V
Accuracy 1 % from 0.5 to 3 VLnp
2 % from 0.05 to 0.5 VLnp
5 % from 0.02 to 0.05 VLnp
Display Format 3 significant digits
Refresh Interval 1 second (typical)
(1) VLnp is an abbreviation that refers to neutral point voltage transformer primary voltage
Operation
This function calculates the value of the main positive sequence voltage V1:
Readout
Access to the measurements is by one of the following:
b the Sepam display via the key
b a PC with SFT2841 software
b communication link
Characteristics
Measurement Range 0.05 to 1.2 VLnp (1)
Units V or kV
Resolution 1V
Accuracy 2 % at VLnp
Display Format 3 significant digits
Refresh Interval 1 second (typical)
(1) VLnp: primary rated phase-to-neutral voltage (VLLp = VLnp/3)
Operation
This function calculates the value of the main negative sequence voltage Vi:
Readout
Access to the measurements is by one of the following:
b the Sepam display via the key
b a PC with SFT2841 software
b a communication link
Characteristics
Measurement Range 0.05 to 1.2 VLnp (1)
Units V or kV
Resolution 1V
Accuracy 2 % at VLnp
Display Format 3 significant digits
Refresh Interval 1 second (typical)
(1) VNp: primary rated phase-to-neutral voltage (VNp = VLnp/3).
Operation
Frequency is measured by the following means:
b based on Vab or Van, if only one phase-to-phase voltage connects to Sepam
b based on positive sequence voltage in other cases
The measurement of the frequency f' is calculated according to the same principle, 2
from V'1 or V'ab or V'an.
Readout
Access to the measurements is by one of the following:
b the Sepam display via the key
b a PC with SFT2841 software
b communication link
b an analog converter with the MSA141 option
Characteristics
Main Channels
Rated Frequency 50 Hz, 60 Hz
Range 25 to 65 Hz
Resolution 0.01 Hz (1)
Accuracy (2) 0.01 Hz
Display Format 3 significant digits
Refresh Interval 1 second (typical)
Additional Channels
Rated Frequency fn 50 Hz, 60 Hz
Range 45 to 55 Hz (fn = 50 Hz)
55 to 65 Hz (fn = 60 Hz)
Resolution (1) 0.01 Hz
Accuracy (2) 0.05 Hz
Display Format 3 significant digits
Refresh Interval 1 second (typical)
(1) On SFT2841
(2) At VLLp, under reference conditions (IEC 60255-6)
Operation
Power values are calculated from the phase currents Ia, Ib and Ic:
b active power = 3.VLLp.I. cos
b reactive power = 3.VLLp.I. sin
b apparent power = 3.VLLp.I. S
Power calculations can be based on the two or three wattmeter method (see table
below), depending on the CTs used.
2 The two wattmeter method is only accurate when there is no residual current. It is
not applicable if the neutral is distributed.
The three wattmeter method gives an accurate calculation of 3-phase and phase by
phase powers in all cases whether or not the neutral is distributed.
Connecting Voltage Connecting Main Current P, Q, S, Calculation Method Power per Phase
Channels Channels Pa, Pb, Pc
Qa, Qb, Qc
Sa, Sb, Sc
3V Ia, Ib, Ic three wattmeters Available
Ia, Ic two wattmeters Not available
Vbc, Vab + Vr Ia, Ib, Ic three wattmeters Available
Ia, Ic two wattmeters Not available
Vbc, Vab without Vr Ia, Ib, Ic, or Ia, Ic two wattmeters Not available
Vab Ia, Ib, Ic, or Ia, Ic two wattmeters Not available
The system voltage is considered to be balanced
Van Ia, Ib, Ic, or Ia, Ic No calculation Pa, Qa, Sa only
Power calculation
b by three wattmeter method:
2 2
b S = P +Q .
DE50770
(1) Choice made in the general settings
Readout
Access to the measurements is by one of the following:
b the Sepam display via the key
b a PC with SFT2841 software
b communication link
b an analog converter with the MSA141 option
Characteristics
2 Measurement Range
Active Power
P, Pa, Pb, Pc
(0.8 % Sn at 999 MW) (1)
Reactive Power
Q, Qa, Qb, Qc
(0.8 % Sn at 999 MVAR) (1)
Apparent Power
S, Sa, Sb, Sc
0.8 % Sn at 999 MVA (1)
Units kW, MW kVAR, MVARr kVA, MVA
Resolution 0.1 kW 0.1 kvar 0.1 kVA
Accuracy 1 % from 0.3 to 1.5 Sn (2) 1 % from 0.3 to 1.5 Sn (3) 1 % from 0.3 to 1.5 Sn
3 % from 0.1 to 0.3 Sn (2) 3 % from 0.1 to 0.3 Sn (3) 3 % from 0.1 to 0.3 Sn
Display Format 3 significant digits 3 significant digits 3 significant digits
Refresh Interval 1 second (typical) 1 second (typical) 1 second (typical)
(1) Sn = 3VLLp.IN.
(2) Cos > 0.8 under reference conditions (IEC 60255-6)
(3) Cos < 0.6 under reference conditions (IEC 60255-6)
Readout
Access to the measurements is by one of the following:
2
b the Sepam display via the key
b a PC with SFT2841 software
b communication link
Resetting to Zero
Access to zero reset is by one of the following:
b via the clear button on the Sepam display if a peak demand is displayed
b via the clear command in the SFT2841 software
b via the communication link (remote control command TC5)
Characteristics
Demand Active Power Demand Reactive Power
Measurement range (1.5 % Sn at 999 MW) (1) (1.5 % Sn at 999 MVAR) (1)
Units kW, MW kvar, MVAR
Resolution 0.1 kW 0.1 kvar
Accuracy 1 %, typical (2) 1 % typical (3)
Display format 3 significant digits 3 significant digits
Integration period 5, 10, 15, 30, 60 minutes 5, 10, 15, 30, 60 minutes
(1) SN = 3VLLp.IN.
(2) At IN, VLLp, cos > 0.8 under reference conditions (IEC 60255-6)
(3) At IN, VLLp, cos < 0.6 under reference conditions (IEC 60255-6)
The + and signs and IND (inductive) and CAP (capacitive) indications give the
direction of power flow and the type of load.
Readout
MT10258
Characteristics
Measurement Range 1 at 1 IND/CAP
Resolution 0.01
Accuracy (1) 0.01 typical
Display Format 3 significant digits
Refresh Interval 1 second (typical)
(1) At IN, VLLp, pf > 0.8 under reference conditions (IEC 60255-6)
2 Readout
Access to the measurements is by one of the following:
b the Sepam display via the key
b a PC with SFT2841 software
b a communication link.
Characteristics
Active energy Reactive energy
Metering Capacity 0 to 2.1 108 MW 0 to 2.1 108 MVAR.h
Units MW.h Mvar.h
Resolution 0.1 MW.h 0.1 MVAR.h
Accuracy 1 % typical (1) 1 % typical (1)
Display Format 10 significant digits 10 significant digits
(1) At IN, VLLp, pf > 0.8 under reference conditions (IEC 60255-6).
The accumulated active and reactive energy values are saved if the system loses
power.
Readout
Access to the measurements is by one of the following:
b a PC with SFT2841 software
b a communication link
Characteristics
Active Energy Reactive Energy
Metering Capacity 0 to 2.1 108 MW.h 0 to 2.1 108 MVAR.h
Units MW.h MVAR.h
Resolution 0.1 MW.h 0.1 MVAR.h
Display Format 10 significant digits 10 significant digits
Increment 0.1 kW.h to 5 MW.h 0.1 kVAR.h to 5 MVAR.h
Pulse 15 ms min. 15 ms min.
Operation
This function gives the temperature value measured by resistance temperature
detectors (RTDs):
b platinum Pt100 (100 at 0 C or 32 F) in accordance with IEC 60751 and
DIN 43760 standards
b nickel Ni120 (100 or 120 at 0 C or 32 F).
If a fault occurs, display of the value is blocked. The associated monitoring function
generates a maintenance alarm.
Readout
The measurements may be accessed via:
b the Sepam display via the key, in C or F
b the display of a PC with the SFT2841 software
b communication link
b an analog converter with the MSA141 option
Characteristics
Range 30 C to +200 C 22 F to +392 F
Resolution 1 C 1 F
Accuracy 1 C from +20 C to +140 C 1.8 F from +68 F to +284 F
2 C from 30 C to +20 C 3.6 F from 22 F to +68 F
2 C from +140 C to +200 C 3.6 F from +284 F to +392 F
Refresh interval 5 seconds (typical)
Operation
Use this function to determine the rotation speed of a motor or generator rotor.
Whenever a rotation is made by the motor or generator shaft, two cams 180 o apart
pass a proximity sensor. Each cam generates a pulse that is transmitted by the
sensor. The time between the two pulses determines the frequency, or rotation
speed of the motor or generator. The number of pulses per rotation is set in the
"particular characteristics" screen of the SFT2841 software. The proximity sensor is
connected to logic input I104.
2
DE10359
Readout
The measurements may be accessed via:
b the Sepam display via the key
b the display of a PC with the SFT2841 software
b the communication link.
Characteristics
Range 0 to 7200 rpm
Resolution 1 rpm
Accuracy 1 rpm
Refresh Interval 1 second (typical)
Pulses per Rotation (R) 1 to 1800 with n R/60 1500
(n: rated speed in rpm)
Proximity Sensor Pass-band (in Hz) > 2.N R/60
Output 24 to 250 V DC, 3 mA minimum
Leakage current < 0.5 mA
in open status
Voltage dip in closed status < 4 V (with 24 V DC power supply)
Pulse duration 0 status > 120 s
1 status > 200 s
Operation
The phasor diagram displays a vectoral picture of the fundamental component of the
raw current and voltage measurements acquired by Sepam. This enables the user
to check cables and implement directional and differential protection functions. The
phasor is programmable and the following choices equip the user to adapt the
diagram according to requirements:
b measurements displayed in the phasor diagram
b reference phasor
b display mode.
Measurements to be Displayed
b phase currents on main and additional channel
2
b residual currents measured or with sum on main and additional channels
b symmetrical components of current I1, I2, Ir/3
b phase-to-neutral voltages on main and additional channels
b phase-to-phase voltages on main and additional channels
b residual voltages on main and additional channels
b symmetrical components of voltage V1, V2, Vr/3.
Reference Phasor
The phasor used as reference is chosen from the phase or residual current or voltage
phasors. Phase shifts of the other phasors displayed are calculated according to this
reference choice. When the reference phasor is too small (< 2 % IN for currents or
5 % VN for voltages), display is impossible.
Display Mode
b Display as true values. The measurements are displayed without any
modification in a scale chosen in relation to the respective rated values:
PE50453
Readout
All the possibilities described above can be accessed via the SFT2841 setting and
operating software.
Two predefined displays are available on the mimic-based UMI:
b the three phase currents and three phase-to-neutral voltages of the main
channels
b the three phase currents of the main channels and the three phase currents of
the additional channels
Characteristics
Diagram Display Options of an SFT2841 Phasor Diagram
Measurements to be Displayed
Multiple selection from: Ia, Ib, Ic, ir, Ir, I1, I2, Ir/3, I'a, I'b, I'c, I'r, I'r
Van, Vbn, Vcn, Vr, Vab, Vbc, Vac, V1, V2, Vr/3
V'an, V'bn, V'cn, V'r, V'ab, V'bc, V'ac
Reference Phasor
Single choice from: Ia, Ib, Ic, Ir, Ir, I'r, I'r
Van, Vbn, Vcn, Vr, Vab, Vbc, Vac,
V'an, V'bn, V'cn, V'r, V'ab, V'bc, V'ac
Display Mode
Current display true (true value)
/ max (value normalized in relation to maximum)
= 1 (normalized to 1)
Voltage display true (true value)
/ max (value normalized in relation to maximum)
= 1 (normalized to 1)
Phase-to-phase voltage wye/delta
Display of scale yes/no
Tripping Context
Operation
This function records the values at the time of tripping (activation of the tripping
contact on output O1). This allows the user to conduct fault analysis to determine
the cause.
In addition to these, the following values are available from the SFT2841 software:
b phase-to-neutral voltages
b negative sequence voltage
b positive sequence voltage
The values for the last five events are saved with the date and time of tripping in case
of a power failure. Each new trip value overwrites the oldest event stored in memory.
Readout
The measurements may be accessed via:
b the Sepam display via the icon
b a PC with SFT2841 software loaded
b the communication link
Operation
This function gives the RMS value of currents at the time of the last trip:
b TripIa: phase a current (main channels)
b TripIb: phase b current (main channels)
b TripIc: phase c current (main channels)
b TripIa: phase a current (additional channels)
tripping order b TripIb: phase b current (additional channels)
30 ms b TripIc: phase c current (additional channels)
Readout
The measurements may be accessed via:
b the Sepam display through the icon
b a PC with SFT2841 software loaded
b communication link
Characteristics
Measurement Range 0.1 to 40 IN (1)
Units A or kA
Resolution 0.1 A
Accuracy 5 % 1 digit
Display Format 3 significant digits
(1) IN, rated current set in the general settings.
The number of phase fault trips is saved in the event of an auxiliary power failure.
2
It can be reinitialized using the SFT2841 software.
Readout
The measurements may be accessed via:
b the Sepam display through the icon
b a PC with SFT2841 software loaded
b the communication link.
Characteristics
Measurement Range 0 to 65535
Units None
Resolution 1
Refresh Interval 1 second (typical)
The number of ground fault trips is saved in the event of an auxiliary power failure.
It can be reinitialized using the SFT2841 software.
Readout
The measurements may be accessed via:
b the Sepam display through the icon
b a PC with SFT2841 software loaded
b the communication link.
Characteristics
Measurement Range 0 to 65535
Units None
Resolution 1
RefreshInterval 1 second (typical)
Operation
This function gives the negative sequence component: T = I2/IB or T = I2/IB.
The negative sequence current is determined based on the phase currents:
b three phases:
1 2
v phase rotation direction a-b-c: I 2 = --- I a + a Ixb + aI c
3
1
2
2
v phase rotation direction a-c-b: I 2 = --- I a + aI xb + a I c
3
b two phases:
1 2
v phase rotation direction a-b-c: I 2 = ------- I a a I c
3
1
v phase rotation direction a-c-b: I 2 = ------- I a aI c
2 3
j -------
3
with x = e
When there are no ground faults, the formulas for 2-phase currents are equivalent to
those for 3-phase currents.
Readout
The measurements may be accessed via:
b the Sepam display via the icon
b a PC with SFT2841 software loaded
b communication link.
Characteristics
Measurement Range 10 to 500 %
Units % IB or % IB
Resolution 1%
Accuracy 2 %
Display Format 3 significant digits
Refresh Interval 1 second (typical)
with:
H1
2
RMS = RMS value of current Ia up to the 13th harmonic
H1 = value of the fundamental of current Ia
Readout
The measurements may be accessed via:
b the Sepam display via the icon
b a PC with SFT2841 software loaded
b communication link.
Characteristics
Measurement Range 0 to 100 %
Units %
Resolution 0.1 %
Accuracy (1) 1 % at IN for Ithd > 2 %
Display Format 3 significant digits
Refresh Interval 1 second (typical)
(1) Under reference conditions (IEC 60255-6).
Readout
The measurements may be accessed via:
b the Sepam display via the icon
b a PC with SFT2841 software loaded
b a communication link.
Characteristics
Measurement Range 0 to 100 %
Units %
Resolution 0.1 %
Accuracy (1) 1 % at VLLN or VN for Vthd > 2 %
Display Format 3 significant digits
Refresh Interval 1 second (typical)
(1) Under reference conditions (IEC 60255-6).
This function gives the phase displacement measured between the residual voltage
and residual current in the trigonometric (counter-clockwise) direction (see diagram).
The measurement is used during commissioning to ensure the directional ground
fault protection unit is connected correctly.
Phase displacement r Three values are available:
b r, angle between Vr and measured Ir
2 b 'r, angle between Vr and measured Ir
b r, angle between Vr and Ir calculated as the sum of the phase currents.
Readout
The measurements may be accessed via:
b the Sepam display through the icon
b a PC with SFT2841 software loaded
b a communication link.
Characteristics
Measurement Range 0 to 359
Resolution 1
Accuracy 2
Refresh Interval 2 seconds (typical)
Phase Displacement a, b, c
Operation
MT11029
This function calculates the phase displacement between the Van, Vbn, Vcn voltages
and Ia, Ib, Ic currents respectively, in the trigonometric (counter-clockwise) direction
(see diagram). The measurements are used when Sepam is commissioned to
Van check voltage and current inputs for correct wiring.
Phase displacement a
When the phase-to-phase voltages Vab and Vbc are connected to Sepam and
there is no measurement of residual voltage Vr, the residual voltage is presumed to
be zero. The function does not operate when only the voltage Vab or Van is
connected to Sepam.
This function recognizes the convention regarding the direction of energy flow in the
outgoing and incoming circuits (see "Power measurements"). Therefore, the angles
a, b, and c are adjusted 180 with respect to the values acquired by Sepam for
the incoming circuits.
Readout
The measurements may be accessed via:
b the Sepam display through the icon
b a PC with SFT2841 software loaded
b communication link.
Characteristics
Measurement Range 0 to 359
Resolution 1
Accuracy 2
Refresh Interval 2 seconds (typical)
Operation
This function records analog signals and logical states. Record storing is initiated
by one or more events set using the SFT2841 software. The stored event begins
before the event (based on the pre-trigger programming) and continues afterwards.
Recordings comprise the following information:
b values sampled from the different signals
b date
b characteristics of the recorded channels
The naming convention for logic input and output data that Logipam uses is also
used in disturbance recording for ease of reading. The duration and number of 2
recordings may be set using the SFT2841 software tool. The files are recorded in
First In First Out (FIFO) type shift storage: when the maximum number of recordings
is reached, the oldest recording is erased when a new recording is triggered.
Transfer
Files will transfer in one of two ways:
b locally, by using a PC connected to the front panel and includes the SFT2841
software tool
b remotely, by using a software tool specific to the remote monitoring and
control system.
Recovery
The SFT2826 software gives the user the ability to recover a recording.
Block Diagram
stored record
MT10181
time
triggering event
Characteristics
Recording content Set-up file:
date, channel characteristics, measuring chain
transformer ratio
Sample file:
recorded signals
Sampling frequency (1) 12 or 36 samples per network period
Analog signals recorded (2) Ia, Ib, Ic, Ir, Ia, Ib, Ic, Ir current channels
Van, Vbn, Vcn, or Vab, Vbc, Van, Vbn, Vcn, Vab, Vbc
phase voltage channels
Vr, VNt or Vr residual voltage channels
Logical states recorded (1) (3) Maximum 32 of the following data:
b all logic inputs / outputs
b pick-up signal
b 1 data item configurable by the logic equation editor or
15 data items configurable by Logipam
(V_FLAGREC, V_FLAGREC2 to V_FLAGREC15)
Number of recordings stored (1) 1 to 19
Total duration of a recording (1) 1 s to 20 s
Maximum recording capacity 22 s at 50 Hz, 12 samples per cycle
(dist. rec. memory usage = 100 %) 18 s at 60 Hz, 12 samples per cycle
7 s at 50 Hz, 36 samples per cycle
6 s at 60 Hz, 36 samples per cycle
Periods recorded before triggering 0 to 99 cycles3
event (1)
File format COMTRADE 97
(1) To be set using the SFT2841 software.
(2) According to type and connection of CTs.
(3) According to Sepam hardware configuration.
Operation
Voltage Comparison
For the sync-check function, the MCS025 module continuously measures the
amplitude, frequency and phase differences between VLLsync1 and VLLsync2.
Out-of-Sync Context
Out-of-sync context gives a precise indication as to why a synchronization request
fails. The context is provided only when the switchgear control function with the
"closing with sync-check" option is activated.
2 When a synchronization request fails, the amplitude, frequency, and phase
differences of the VLLsync1 and VLLsync2 voltages measured by the MCS025
module are recorded, with the date and time, at the end of the switchgear control
function "closing request time" delay.
Readout
The amplitude, frequency and phase differences and out-of-sync context can be
accessed via:
b Sepam display by using the icon
b a PC with SFT2841 software loaded
b a communication link.
Characteristics
Amplitude Difference
Measurement Range 0 to 120 % of VLLsync1 (or VLnsync1)
Unit % of VLLsync1 (or VLnsync1)
Resolution 0.1 %
Accuracy 2 %
Refresh Interval 1 second (typical)
Frequency Difference
Measurement Range 0 to 10 Hz
Unit Hz
Resolution 0.01 Hz
Accuracy 0.05 Hz
Refresh Interval 1 second (typical)
Phase Difference
Measurement Range 0 to 359
Unit
Resolution 1
Accuracy 2
Refresh Interval 1 second (typical)
Resetting to Zero
The thermal capacity used can be reset to zero, after entering a password on:
b a Sepam display via the clear key
b a PC with SFT2841 software
Characteristics
Measurement Range 0 to 800 %
Units %
Display Format 3 significant digits
Resolution 1%
Refresh Interval 1 second (typical)
The machine thermal overload function has two groups of thermal settings for cases
such as natural or forced ventilation or two-speed motors. A time constant is
estimated for each group of thermal settings.
Readout
Measurements are accessed via:
b the Sepam display by means of the key
b a PC with SFT2841 software loaded
b a communication link.
Characteristics
Measurement Range 5 to 600 min
Units min
Resolution 1 min
Accuracy 5 %
Display Format 3 significant digits
Readout
The measurements may be accessed via:
b a Sepam display via the icon
b a PC with SFT2841 software loaded
b a communication link.
Characteristics
Measurement Range 0 to 999 min
Units min
Display Format 3 significant digits
Resolution 1 min
Refresh Interval 1 second (typical)
Readout
The measurements may be accessed via:
b a Sepam display through the icon
b a PC with SFT2841 software loaded
b a communication link.
Characteristics
Measurement Range 0 to 999 min
Units min
Display Format 3 significant digits
Resolution 1 min
Refresh Interval 1 second (typical)
The initial counter value can be modified using the SFT2841 software.
Characteristics
Range 0 to 65535
Units hours
currents exceeds 1.2 IB and the moment at which the three currents drop back below
1.2 IB. The maximum phase current obtained during this period is the starting
current. The two values are saved in case auxiliary power fails.
Readout
Measurements are accessed via:
b the Sepam display via the key
b a PC with SFT2841 software loaded
b a communication link.
1.2 IB
Characteristics
Starting Time
IB Measurement Range 0 to 300 s
Units s or ms
Display Format 3 significant digits
Resolution 10 ms or 1 digit
Refresh Interval 1 second (typical)
Starting Current
Measurement Range 1.2 IB at 24 IN (1)
Units A or kA
Display Format 3 significant digits
Resolution 0.1 A or 1 digit
Refresh Interval 1 second (typical)
(1) Or 65.5 kA.
Resetting to Zero
The number of starts counters may be reset to zero, after entry of a password, on:
b the Sepam display via the clear icon
b a PC with SFT2841 software loaded
Characteristics
Measurement Range 0 to 60
Units None
Display Format 3 significant digits
Resolution 1
Refresh Interval 1 second (typical)
Readout
The number of starts and waiting time may be accessed via:
b the Sepam display via the key
b a PC with SFT2841 software loaded
b a communication link.
Characteristics
Measurement Range 0 to 360 min
Units min
Display Format 3 significant digits
Resolution 1 min
Refresh Interval 1 second (typical)
Ia Ib Ic Ic Ib Ia Differential Current
DE50311
Operation
The differential current Id is calculated to facilitate the implementation of the
ANSI 87T and ANSI 87M differential protection functions:
b for a rotating machine (ANSI 87M), it is calculated for each phase by:
I d = I + I
b when a transformer is used (ANSI 87T), the Id calculation takes into account
the vector shift and transformation ratio:
I d = Irec + Irec
2
The Id value is expressed with respect to IN1, the rated current of the main channels.
Readout
The measurements may be accessed via:
b the Sepam display by using the icon
b a PC with SFT2841 software loaded
b a communication link.
Characteristics
Measurement Range 0.015 to 40 IN
Units A or kA
Resolution 0.1 A
Accuracy (1) 5 %
Display Format 3 significant digits
Refresh Interval 1 second (typical)
(1) At IN, under reference conditions (IEC 60255-6).
Through Current
Operation
The through current It is calculated to facilitate the implementation of the ANSI 87T
and ANSI 87M differential protection functions:
b for a rotating machine (ANSI 87M), it is calculated for each phase by:
I I
It = -------------
-
2
b when a transformer is used (ANSI 87T), the It calculation takes into account
the vector shift and transformation ratio:
Readout
The measurements may be accessed via:
b the Sepam display via the icon
b a PC with SFT2841 software loaded
b a communication link.
Characteristics
Measurement range 0.015 to 40 IN
Units A or kA
Resolution 0.1 A
Accuracy (1) 5 %
Display format 3 significant digits
Refresh interval 1 second (typical)
(1) At IN, under reference conditions (IEC 60255-6).
Operation
Current phase displacement between the main phase currents (I) and additional
DE50287
The measurements are corrected by taking account of the connection and the
direction of rotation of the phases to create an image of the vector shift, which must
be set in order to use the ANSI 87T differential protection: r/30 = vector shift (Setting
ranges). This is the protectioin setting range.
2 Readout
The measurements may be accessed via:
b the Sepam display via the icon
b a PC with SFT2841 software loaded
b a communication link.
Characteristics
Measurement Range 0 to 359
Units
Resolution 1
Accuracy (1) 2
Display Format 3 significant digits
Refresh Interval 1 second (typical)
(1) At IN, under reference conditions (IEC 60255-6).
Readout
The measurement may be accessed via: 2
b a PC with SFT2841 software loaded
b a communication link.
Characteristics
Measurement Range 0 to 200 k
Units
Resolution 0.001
Accuracy (1) 5 %
Refresh Interval 1 second (typical)
(1) At IN, VN, under reference conditions (IEC 60255-6).
Vbc with I bc = I b I c
Z bc = --------------
I bc
Vac with I ac = I c I a
Z ac = --------------
I ac
Readout
The measurement may be accessed via:
b a PC with SFT2841 software loaded
b a communication link.
Characteristics
Measurement Range 0 to 200 k
Units
Resolution 0.001
Accuracy (1) 5 %
Refresh Interval 1 second (typical)
(1) At IN, VN, under reference conditions (IEC 60255-6).
Readout
The measurements may be accessed via:
2 b
b
the Sepam display via the
a PC with SFT2841 software loaded
key
b a communication link.
Characteristics
Measurement range 0.2 to 30 % of Vnt
Units % of Vnt
Resolution 0.1 %
Accuracy (1) 1 %
Refresh interval 1 second (typical)
(1) Under reference conditions (IEC 60255-6).
The value is used for implementing the third harmonic undervoltage protection
function (ANSI 27TN/64G2).
Readout
The measurements may be accessed via:
b the Sepam display by using the icon
b a PC with SFT2841 software loaded
b a communication link.
Characteristics
Measurement Range 0.2 to 90 % of VLnp
Units % fo VLnp
Resolution 0.1 %
Accuracy (1) 1 %
Refresh Interval 1 second (typical)
(1) Under reference conditions (IEC 60255-6).
Operation
This operation provides the user with the total capacitance for each phase of the
connected capacitor bank steps. The user can then monitor the condition of the
capacitors.
It covers wye and delta connections (a parameter that is set in the "Particular
characteristics" screen of the SFT2841 setting and operating software). For this
measurement, the installation is considered a perfect capacitance, without
considering the resistances added by connecting the capacitor bank steps.
Readout
The capacitance measurements can be accessed via:
b a PC with SFT2841 software loaded
b a communication link.
Characteristics
Measurement Range 0 to 30 F
Unit F, mF or F
Resolution 0.1 F
Accuracy 5 %
Refresh Interval 1 second (typical)
Accuracy
The measurement accuracy is valid if the resistance and inductance per phase of the
capacitor bank connecting cable (cable between the Sepam CT and the capacitor
bank) allow for the following conditions:
Operation
This function measures the unbalance current of double wye-connected capacitor
DE10412
Readout
The measurements may be accessed through:
Step 1
b the Sepam display key
b a PC with SFT2841 software
b a communication link.
Step 2 Characteristics
Measurement Range 0.02 to 20 IN
Unit A
Resolution 0.1 A
Accuracy 5 %
Step 3 Refresh Interval 1 second (typical)
Step 4
DE10413
voltage measurement chain:
b voltage transformers
b VT connection to Sepam
b Sepam voltage analog inputs.
There are two units for the function, one for supervision
of the main voltage channel VTs and the other for
supervision of the additional voltage channel VTs. 2
The function processes the following failures:
b partial loss of phase voltages, detected by:
v presence of negative sequence voltage
v and absence of negative sequence current
b loss of all phase voltages, detected by:
v presence of current on one of the three
phases
v and absence of all measured voltages
b tripping of the phase VT (and/or residual VT)
protection relay, detected by the acquisition on a
logic input of the fuse blown contact or auxiliary
contact of the circuit breaker protecting the VTs
b other types of failures may be processed using
the logic equation editor.
The "Phase voltage fault" and "Residual voltage fault"
Block Diagram: Residual Voltage Fault Detection.
information disappear automatically when:
b the cause of the fault disappears
DE10414
The behavior of the protection functions in the event of a "Phase voltage fault" or
Residual voltage fault" is to be set up and the following choices are proposed:
b for protection functions 21B, 27, 27D, 27TN, 32P, 32Q, 37P, 40, 47, 50/27,
51V, 59N, 59, 78PS: blocking or no blocking
b for protection function 67: blocking or non-directional operation (50/51)
b for protection function 67N/67NC: blocking or non-directional operation
(50N/ 51N).
Setting Advice
The partial loss of voltages is based on detecting the presence of negative sequence
voltage and the absence of negative sequence current.
By default:
b the presence of negative sequence voltage is detected when: V2 > 10 % VLnp
(Vs2)
b the absence of negative sequence current is detected when: I2 < 5 % IN (Is2)
b time delay T1 is 1 second.
These default settings ensure the stability of the VT supervision function in the event
2 of short-circuits or transient phenomena on the network. The Is2 set point may be
raised for highly unbalanced networks.
Time delay T1 is to be set shorter than the voltage and power protection function
tripping times.
Time delay T2 for the detection of the loss of all voltages must be longer than the time
it takes for a short-circuit to be cleared by the protection function 50/51 or 67, to avoid
the detection of a VT loss of voltage fault triggered by a 3-phase short-circuit.
The time delay for the 51V protection function must be longer than the T1 and T2 time
delays used for the detection of voltage losses.
Characteristics
Validating the Detection of Partial Loss of Phase Voltages
Setting Yes / No
Vs2 Set Point
Setting 10 % to 100 % of VLnp
Accuracy 5 %
Resolution 1%
Pick-up / drop-out ratio 95 % 2.5 %
Is2 Set Point
Setting 5 % to 100 % of IN
Accuracy 5 %
Resolution 1%
Pick-up / drop-out ratio 105 % 2.5 % or > (1 + 0.01 IN/Is2) x 100 %
Time Delay T1 (Partial Loss of Phase Voltages)
Setting 0.1 s to 300 s
Accuracy 2 % or 25 ms
Resolution 10 ms
Validating the Detection of the Loss of All Phase Voltages
Setting Yes / No
Detecting the Loss of All Voltages with Verification of the Presence of Current
Setting Yes / No
Voltage Presence Detected by
Setting Breaker closed / Logic equation
Time Delay T2 (Loss of All Voltages)
Setting 0.1 s to 300 s
Accuracy 2 % or 25 ms
Resolution 10 ms
Voltage and Power Protection Behavior
Setting No action / block
Protection 67 Behavior
Setting Non-directional / block
Protection 67N/67NC Behavior
Setting Non-directional / block
Inputs
Designation Syntax Equations Logipam
Phase VT fault PVTS_x_103 b b
Blocking function PVTS_x_113 b b
Voltage presence PVTS_x_117 b b
Outputs
Designation Syntax Equations Logipam Matrix
Function output PVTS_x_3 b b b
Function blocked PVTS_x_16 b b
Note: x = unit number: x = 1: main channels (V).
x = 2: additional channels (V).
Operation
The Current Transformer (CT) supervision function is used to supervise the complete
phase current measurement chain:
b phase CTs (1A / 5A CTs or LPCTs)
b phase current CT connection to Sepam
b Sepam phase current analog inputs
There are two units for the function, one for supervising the main current channel
CTs (I) and the other for supervising the additional current channel CTs (I).
The function is inactive if only two phase CTs are connected.
The "Main CT fault" or "Additional CT fault" information disappears automatically
when three phase currents are measured and have values greater than 10 % of IN.
2
If a phase current is lost, the following protection functions can be blocked to avoid
nuisance tripping:
b 21B, 46, 40, 32P, 37P, 32Q, 78PS, 64REF
b 51N and 67N, if Ir is calculated by the sum of the phase currents.
Block Diagram
DE10415
Ia < 1 % IN
Ib > 5 % IN
< 1.2 IN
T1 0 CT fault
Ic PCTS_x_3
> 5 % IN
< 1.2 IN
Ib
Ic 110 < angle (Ic, Ib) <130
Loss of phase b
Loss of phase c
Characteristics
Time Delay
Setting 0.15 s to 300 s
Accuracy 2 % or 25 ms
Resolution 10 ms
Blocking Protection Functions 21B, 32P, 32Q, 37P, 40, 46, 51N, 64REF, 67N, 78PS
Setting No action / block
Inputs
Designation Syntax Equations Logipam
Block function PCTS_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Delayed output PCTS_x_3 b b b
Phase a fault PCTS_x_7 b b
Phase b fault PCTS_x_8 b b
Phase c fault PCTS_x_9 b b
Function blocked PCTS_x_16 b b
Note: x = unit number: x = 1: main channels (l).
x = 2: additional channels (l).
DE50111
_ (NO) or normally closed (NC) trip units. It blocks breaker operation under false
a _ 52 conditions.
With NO units, the function detects:
b circuit continuity
2 H1
N.O.
b supply loss
b mismatching of position indication contacts
a
With NC units, the function only detects a mismatch of position indication contacts; it
b
does not check for circuit continuity or supply loss. Trip unit supervision is
b
considered unnecessary in this case.
Connection when trip circuit Connection when trip circuit
is wired with NO contacts is wired with NC contacts The information is accessible in the matrix ("trip circuit" message) and by the remote
indication TS1.
Block Diagram
DE10416
Outputs
Designation Syntax Equations Logipam Matrix
Trip circuit supervision fault V_TCS b b
N.O.
Closing Circuit Supervision
DE10365
52
Operation
This function monitors closing coil continuity. It calls for the wiring diagram (opposite),
_ connected to a logic input configured with the "Closing coil supervision" function.
b The information is accessible in the matrix ("closing circuit" message) and via remote
indication TS234.
Block Diagram
DE10417
Outputs
Designation Syntax Equations Logipam Matrix
Control fault V_CTRLFAUT b b
(circuit breaker monitoring)
Operation
The auxiliary power supply is an important factor in cubicle operation. This function
monitors the supply by measuring the Sepam power supply voltage and comparing
the measured value to low and high thresholds. If the value is outside these limits,
an alarm is generated. The related information is available in the matrix and in
Logipam.
Block Diagram
DE10418
Sepam power
supply (Vaux)
Readout
The measurements can be accessed one of the following:
b the Sepam display via the icon
b a PC with SFT2841 software
b a communication link.
Characteristics
Measured Auxiliary Voltage Vaux, Low Threshold Alarm, High Threshold Alarm
Measurement Range 20 to 275 V DC
Units V
Resolution 0.1 V (1 V on display)
Accuracy 7 %
Refresh Interval 1 second (typical)
Rated Auxiliary Voltage
Setting 24 to 250 V DC
Resolution 1V
Low Threshold
Setting 60 to 95 % of rated V (minimum 20 V)
Resolution 1V
Accuracy 7 %
High Threshold
Setting 105 to 150 % of rated V (maximum 275 V)
Resolution 1V
Accuracy 7 %
Outputs
Designation Syntax Equations Logipam Matrix
Auxiliary power supply V_VAUX_ON b
monitoring on
High threshold alarm V_VAUX_HIGH b b
Low threshold alarm V_VAUX_LOW b b
Each value is monitored by an adjustable set point. When the set point is exceeded,
an alarm is sent and is available in the matrix and by the remote indication TS235.
These values are saved in the event of an auxiliary power loss. The initial values can
be set using the SFT2841 software tool to take into account the actual state of a
breaking device used.
The higher number of trips at the higher currents causes more wear on breaker
contacts and decreases their life. Refer to switchgear documentation for contact
wear specifications.
Readout
The measurements may be accessed via:
b the Sepam display via the icon
b a PC with SFT2841 software
b a communication link.
Characteristics
Cumulative breaking current measured
Range 0 to 65535 (kA)2
Units primary (kA)2
Resolution 1(kA)2
Accuracy (1) 10 % 1 digit
Alarm set point
Setting 0 to 65535 (kA)2
Resolution 1(kA)2
Accuracy (1) 10 % 1 digit
Outputs
Designation Syntax Equations Logipam Matrix
Cumulative breaking current V_MAXBRKCUR b b
threshold overrun
(1) At IN, under reference conditions (IEC 60255-6).
Number of Operations
Operation
The function also gives the total number of breaking device operations. It is activated
by tripping the 01 contact.
Readout
The measurements may be accessed via:
b the Sepam display via the key
b a PC with the SFT2841 software
b communication link.
Characteristics
Range 0 to 4.109
Units None
Resolution 1
Refresh Interval 1 second (typical)
Operating Time
Operation
This function gives the value of the opening operating time of a breaking device (1)
and change of status of the device open position contact connected to the I102 input (2)
The value is saved in the event of an auxiliary power failure.
Readout
The measurements may be accessed by one of the following:
b
b
a Sepam display through the
a PC with SFT2841 software
icon 2
b communication link.
(1) Refer to the vendor-provided documentation on the switchgear used for operating time
parameter specifications.
(2) Optional I/O module.
Characteristics
Measurement Range 20 to 100
Units millisecond (ms)
Resolution 1 ms
Accuracy 1 ms typical
Display Format 3 significant digits
Charging Time
Operation
This function gives the charge time value of the breaking device (1) operating
mechanism. This value is determined by the device closed position status change
contact and the end of charging contact connected to the Sepam logic inputs (2).
The value is saved in the event of an auxiliary power failure.
Readout
The measurements may be accessed via:
b the Sepam display via the key
b the display of a PC with the SFT2841 software
b the communication link.
(1) Refer to the vendor-provided documentation on the switchgear used for operating time
parameter specifications.
(2) Optional I/O module.
Characteristics
Measurement Range 1 to 20
Units seconds
Resolution 1 second
Accuracy 0.5 second
Display Format 3 significant digits
Operation
This function keeps a count of circuit breaker or contactor "rackouts", or disconnects.
The information can be used for breaking device maintenance. The breaking
devices "racked out" or "disconnected" position contacts must be wired to a logic
input and set up in the SFT2841 software in order for rackouts to be counted.
2 Readout
The measurements can be accessed by one of the following:
b Sepam display via the icon
b a PC with SFT2841 software loaded
b a communication link.
Characteristics
Measurement Range 0 to 65535
Units None
Resolution 1
Refresh Interval 1 second (typical)
Setting Ranges 60
Overspeed 66
Underspeed 67
Underimpedance 68
Overexcitation (V/Hz) 69
Sync-Check 71
Undervoltage (L-L or L-N) 73
Positive Sequence Undervoltage &
Phase Rotation Direction Check 74
Remnant Undervoltage 75
Third Harmonic Undervoltage 76
Directional Active Overpower
Directional Reactive Overpower
80
81
3
Phase Undercurrent 82
Directional Active Underpower 83
Temperature Monitoring 84
Loss of Field 85
Negative Sequence/Current Unbalance 88
Negative Sequence Overvoltage 91
Excessive Starting Time, Locked Rotor 92
Thermal Overload for Cables 94
Thermal Overload for Capacitors 99
Thermal Overload for Machines 108
Breaker Failure 119
Inadvertent Energization 121
Phase Overcurrent 123
Ground Fault 125
Voltage-Restrained Overcurrent 128
Capacitor Bank Unbalance 130
Overvoltage (L-L or L-N) 131
Neutral Voltage Displacement 132
100% Stator Ground Fault 133
Restricted Ground Fault Differential 134
Starts per Hour 136
Directional Phase Overcurrent 137
Directional Ground Fault - Type 1 140
Directional Ground Fault - Type 2 143
Directional Ground Fault - Type 3 145
Pole Slip 147
Recloser 151
Overfrequency 155
Underfrequency 156
Rate of Change of Frequency (df/dt) 157
Machine Differential 160
Transformer Differential 163
General 172
(1) Sn = 3 IN.VLLp
Measurement origin
IDMT (IDMT; reset time)
Ir input, Ir input, sum of phase currents Ir or sum of phase currents Ir
0.5 s to 20 s
3
ANSI 50V/51V - Voltage-Restrained Overcurrent
Tripping Time Delay Timer Hold
Tripping curve Definite time DT
SIT, LTI, VIT, EIT, UIT (1) DT
RI DT
IEC: SIT/A, LTI/B, VIT/B, EIT/C DT or IDMT
IEEE: MI (D), VI (E), EI (F) DT or IDMT
IAC: I, VI, EI DT or IDMT
Customized DT
Is set point 0.5 to 24 IN Definite time Inst; 0.05 s to 300 s
0.5 to 2.4 IN IDMT 0.1 s to 12.5 s at 10 Is
Timer hold Definite time (DT; timer hold) Inst; 0.05 s to 20 s
IDMT (IDMT; reset time) 0.5 s to 300 s
Measurement origin Main channels (I) or additional channels (I)
ANSI 51C - Capacitor Bank Unbalance
Is set point 0.05 A to 2 IN Definite time 0.1 to 300 s
ANSI 59 - Overvoltage (L-L) or (L-N)
Set point and time delay 50 to 150% of VLLp 0.05 to 300 s
Measurement origin Main channels (V) or additional channels (V)
ANSI 59N - Neutral Voltage Displacement
Tripping curve Definite time
IDMT
Set point 2 to 80% of VLLp Definite time 0.05 to 300 s
2 to 10% of VLLp IDMT 0.1 to 100 s
Measurement origin Main channels (V), additional channels (V) or neutral-point voltage VLnt
ANSI 64REF - Restricted Ground Fault Differential
Isr set point 0.05 to 0.8 IB (IB 20 A)
0.1 to 0.8 IB (IB < 20 A)
Measurement origin Main channels (I, Ir) or additional channels (I, Ir)
ANSI 66 - Starts per Hour
Total number of starts 1 to 60 Period 1 to 6 h
Number of consecutive starts 1 to 60 T time delay stop/start 0 to 90 min
(1) Tripping as of 1.2 Is.
3 to 18 IN1
3
Percentage-Based Curve
Ids set point 30 to 100% IN1
Slope Id/It 15 to 50%
Slope Id/It2 Without, 50 to 100%
Slope change point 1 to 18 IN1
Restraint on Energization
Isinr set point 1 to 10%
Delay 0 to 300 s
Restraint on CT Loss
Activity On / Off
Harmonic Restraints Conventional Self-Adaptive
Selection of restraint Conventional Self-adaptive
High set point On On / Off
Harmonic 2 percentage set point Off, 5 to 40%
Harmonic 2 restraint Phase-specific/Global
Harmonic 5 percentage set point Off, 5 to 40%
Harmonic 5 restraint Phase-specific/Global
The protection activates if the measured speed exceeds the speed set point. The
protection includes a definite time delay T.
3 Block Diagram
DE50764
Rotor Speed
measurement ()
I104
Characteristics
Settings
Set Point s
Setting range 100 to 160% of n
Accuracy (1) 2%
Resolution 1%
Drop out/pick up ratio 95%
Time Delay T
Setting range 1 s to 300 s
Accuracy (1) 25 ms or (60000/(s (2) x R (3))) ms
Resolution 1s
Inputs
Designation Syntax Equations Logipam
Protection reset P12_x_101 b b
Protection blocking P12_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P12_x_1 b b
Delayed output P12_x_3 b b b
Protection blocked P12_x_16 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
(2) s in rpm.
(3) R: Number of pulses (cam) per rotation.
The "Rotor speed measurement" function must be assigned to logic input I104 for the
function to work.
The protection function picks up if the speed measured drops below the speed set
point after having first exceeded the set point by 5%. Zero speed is detected by unit
3
1 and is used by protection function 48/51 LR to detect rotor locking.
The protection includes a definite (DT) time delay T.
Block Diagram
DE51539
Rotor Speed
measurement ()
I104
Characteristics
Settings
Set Point s
Setting range 10 to 100% of n
Accuracy (1) 2%
Resolution 1%
Drop out/pick up ratio 105%
Time Delay T
Setting range 1 s to 300 s
Accuracy (1) 25 ms or (60000/(s (2) x R (3))) ms
Resolution 1 s with T > (60/(s (2) x R (3)))
Inputs
Designation Syntax Equations Logipam
Protection reset P14_x_101 b b
Protection blocking P14_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P14_x_1 b b
Delayed output P14_x_3 b b b
Protection blocked P14_x_16 b b
Zero speed P14_x_38 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
(2) s in rpm.
(3) R: Number of pulses (cam) per rotation.
Block Diagram
DE51540
Characteristics
Settings
Set Point s
Setting range 0.05VN/IB Zs 2 VN/IB or 0.001
Accuracy (1) 2%
Resolution 0.001 or 1 digit
Drop out/pick up ratio 105%
Time Delay T
Setting range 200 ms T 300 s
Accuracy (1) 2% or from 10 ms to +25 ms
Resolution 10 ms or 1 digit
Characteristic Times (1)
Operation time pick-up < 35 ms from infinite to Zs/2 (typically 25 ms)
Overshoot time < 40 ms
Reset time < 50 ms
Inputs
Designation Syntax Equations Logipam
Protection reset P21B_1_101 b b
Protection blocking P21B_1_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P21B_1_1 b b
Delayed output P21B_1_3 b b b
Protection blocked P21B_1_16 b b
(1) Under reference conditions (IEC 60255-6).
This protection function is used to back up other protection functions. Its setting must
ensure discrimination with the other protection functions.
T = 0.9 s, for example, for a network where faults are cleared in 0.6 s.
The protection function picks up when the VLL/f or VLn/f ratio (depending on VT
configuration) exceeds the set point. The function is delayed (definite time (DT) or
IDMT) according to three curves (see tripping curve equation on page 173).
Block Diagram
3
DE51541
Characteristics
DE50718
10,000 Settings
VT Configuration
Setting range Delta / Wye
1,000 Tripping Curve
Setting range Definite time
IDMT: type A, type B, type C
100
Gs Set Point
Setting range 1.03 to 2.0 pu (2)
10 Accuracy (1) 2%
Resolution 0.01 pu (2)
Drop out/pick up ratio 98% 1%
1 Time Delay T (Operation Time at 2 pu)
1 1.1 1.2 1.3 1.4 1.5 1.6 1.7 1.8 1.9 2 2.1
Definite time Setting range 0.1 to 20000 s
Voltage/frequency ratio Inverse Definite Minimum Time (IDMT) Accuracy (1) 2% or from 10 ms to +25 ms
tripping curves IDMT Setting range 0.1 to 1250 s
3 Resolution
Accuracy (1) 2% or from 10 ms to +25 ms
10 ms or 1 digit
Characteristic Times (1)
Operation time pick-up < 40 ms from 0.9 Gs to 1,1 Gs at fn
Overshoot time < 40 ms from 0.9 Gs to 1.1 Gs at fn
Reset time < 50 ms from 1.1 Gs to 0.9 Gs at fn
Inputs
Designation Syntax Equations Logipam
Protection reset P24_x_101 b b
Protection blocking P24_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P24_x_1 b b
Delayed output P24_x_3 b b b
Protection blocked P24_x_16 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
(2) 1 pu represents 1 x Gn.
100
b an IDMT set point, set to 1.05 Gn with a long delay
Example: type B curve, Gs1 = 1.05 and T1 = 8 s
b a definite time (DT) set point, set to approximately 1.2 Gn with a tripping time
10 of approximately ten seconds.
0.1
1 1.1 1.2 1.3 1.4 1.5 1.6
Example 2. Transformer
A transformer is generally protected by an IDMT set point, set to 1.05 Gn with a long
DE50662
delay
0.1
1 Gs 1.1 1.2 1.3 1.4 1.5 1.6
The function is available in the optional MCS025 module. The "Close enable" logic
data must connect to a logic input on the Sepam. All other data and measurements
are transmitted to the Sepam base unit through the CCA785 connection cord.
Block Diagram
3
DE80143
Anticipation
It is possible to anticipate the function by a time, Ta, compensating for the frequency
difference and the circuit breaker closing time in order to synchronize the voltages at
the time of closing.
Voltage Checking
When one of the two voltages is absent, closing may be authorized according to one
of five voltage checking modes.
b VLLsync1 absent and VLLsync2 present (Dead1 AND Live2)
b VLLsync1 present and VLLsync2 absent (Live1 AND Dead2)
b One voltage is present and the other is absent (Dead1 XOR Dead2)
b One or both of the two voltages are absent (Dead1 OR Dead2)
b Both voltages are absent (Dead1 AND Dead2).
The presence of each of the voltages is detected by comparing the voltage to the
high set point (VLLs high set point). The absence of either of the voltages is detected
by comparing the voltage to the low set point (VLLs low set point).
User Information
The following measurements are available:
b voltage difference
b frequency difference
b phase difference.
Characteristics
Settings
dVLLs Set Point
Setting range 3% to 30% VLLsync1
Accuracy (1) 2.5% or 0,003 VLLsync1
Resolution 1%
Drop out/pick up ratio 106%
dfs Set Point
Setting range 0.05 Hz to 0.5 Hz
Accuracy (1) 10 mHz
3 Resolution
Drop out/pick up
0.01 Hz
< 15 mHz
dPhis Set Point
Setting range 5 to 50
Accuracy (1) 2
Resolution 1
Drop out/pick up ratio 120%
VLLs High Set Point
Setting range 70% to 110% VLLsync1
Accuracy (1) 1%
Resolution 1%
Drop out/pick up ratio 93%
VLLs Low Set Point
Setting range 10% to 70% VLLsync1
Accuracy (1) 1%
Resolution 1%
Drop out/pick up ratio 106%
Anticipating Circuit Breaker Closing Time
Setting range 0.1 to 500 s
Accuracy (1) 2% or 25 ms
Resolution 10 ms or 1 digit
Voltage Checking
Setting range On / Off
Operating Mode with No Voltage
Setting range Dead1 AND Live2
Live1 AND Dead2
Dead1 XOR Dead2
Dead1 OR Dead2
Dead1 AND Dead2
Characteristic Times (1)
Operation time < 190 ms
dVLL operation time < 120 ms
df operation time < 190 ms
dPhi operation time < 190 ms
Reset time < 50 ms
Outputs (1)
Designation Syntax Equations Logipam Matrix
Close enable
Sync-check P25_1_46 b b
No voltage P25_1_47 b b
Phase difference P25_1_49 b b
Frequency difference P25_1_50 b b
Voltage difference P25_1_51 b b
No VLLsync1 P25_1_52 b b
No VLLsync2 P25_1_53 b b
(1) Under reference conditions (IEC 60255-6).
DE51374
delayed output Vca (or Vcn)
Description
Vab (or Van)
Undervoltage monitoring protects motors against the
negative effects of low system voltages. It also detects
abnormally low network voltage in order to trigger
Vbc (or Vbn)
automatic load shedding or source transfer:
b the protection function is single-phase and
operates with phase-to-neutral or phase-to-
Vca (or Vcn)
phase voltage
b it includes a definite (DT) or IDMT time delay T in
phase-to-neutral operation (see tripping curve
equation on page 173)
b it indicates the faulty phase in the alarm
associated with the fault.
Operation with phase-to-neutral or phase-to-phase
voltage depends on the connection selected for the instantaneous output Vab (or Van)
instantaneous output Vbc (or Vbn)
3
voltage inputs.
instantaneous output Vca (or Vcn)
Connection Conditions
Type of connection Van, Vbn, Vab, Vbc Vab, Vbc
Vcn (1) + Vr
Phase-to-neutral operation YES YES NO Characteristics
Phase-to-phase operation YES YES YES Settings
Measurement Origin
Type of connection Vab (1) Va (1) Setting range Main channels (VLL) / Additional channels (VLL)
Phase-to-neutral operation NO On Van only Voltage Mode
Phase-to-phase operation On Vab only NO Setting range Phase-to-phase voltage / Phase-to-neutral voltage
(1) With or without Vr Tripping Curve
Setting range Definite / IDMT
VLLs (or VLns) Set Point
Setting range 5% of VLLp (or VLnp) to 100% of VLLp (or VLnp)
Accuracy (1) 2% or 0.005 VLLp
Resolution 1%
Drop out/pick up ratio 103% 2%
Time Delay T (Tripping Time for Zero Voltage)
Setting range 50 ms to 300 s
Accuracy (1) 2% or 25 ms
Resolution 10 ms or 1 digit
Characteristic Times
Operation time Pick-up < 40 ms from 1.1 VLLs (VLns) to 0.9 VLLs
(VLns) (typically 25 ms)
Overshoot time < 40 ms from 1.1 VLLs (VLns) to 0.9 VLLs (VLns)
Reset time < 50 ms from 0.9 VLLs (VLns) to 1.1 VLLs (VLns)
Inputs
Designation Syntax Equations Logipam
Protection reset P27_x_101 b b
Protection blocking P27_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P27_x_1 b b
Delayed output P27_x_3 b b b
Fault phase a(2) P27_x_7 b b
Fault phase b (2) P27_x_8 b b
Fault phase c(2) P27_x_9 b b
Protection blocked P27_x_16 b b
Instantaneous output Van or Vab P27_x_23 b b
Instantaneous output Vbn or Vbc P27_x_24 b b
Instantaneous output Vcn or Vac P27_x_25 b b
Delayed output Van or Vab P27_x_26 b b
Delayed output Vbn or Vbc P27_x_27 b b
Delayed output Vcn or Vac P27_x_28 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
(2) When the protection function is used for phase-to-neutral voltage.
This protection also detects the phase rotation direction. The protection function
considers that the phase rotation direction is reversed when the positive sequence
voltage is less than 10% of VLLp and when the phase-to-phase voltage is greater
than 80% of VLLp. When this is the case, the alarm message "ROTATION " is
generated.
Block Diagram
3
DE51544
V1 V1 < V1s
Characteristics
Settings
Measurement Origin
Setting range Main channels (VLL) / Additional channels (VLL)
Vs1 Set Point
Setting range 15% VLLp to 60% VLLp
Accuracy (1) 2% or 0.005 VLLp
Resolution 1%
Drop out/pick up ratio 103% 2%
Time Delay T
Setting range 50 ms to 300 s
Accuracy (1) 2% or 25 ms
Resolution 10 ms or 1 digit
Characteristic Times
Operation time Pick-up < 40 ms from1.1 Vsd to 0.9 Vsd
Overshoot time < 40 ms from1.1 Vs1 to 0.9 Vs1
Reset time < 50 ms from 0.9 Vs1 to 1.1 Vs1
Inputs
Designation Syntax Equations Logipam
Protection reset P27D_x_101 b b
Protection blocking P27D_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P27D_x_1 b b
Delayed output P27D_x_3 b b b
Protection blocked P27D_x_16 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
This is single-phase protection. It enables when the Vab or Van voltage is less than
the VLLs set point. The protection includes a definite time delay.
Block Diagram
DE50768
Vab
(or Van)
Characteristics
Settings
Measurement Origin
3
Setting range Main channels (VLL) / Additional channels (VLL)
VLLs Set Point
Setting range 5% to 100% VLLp
Accuracy (1) 5% or 0.005 VLLp
Resolution 1%
Drop out/pick up ratio 103% 2%
Time Delay T
Setting range 50 ms to 300 s
Accuracy (1) 2% or 25 ms
Resolution 10 ms or 1 digit
Characteristic Times
Operation time Pick-up < 45 ms from 1.1 VLLs to 0.9 VLLs
Overshoot time < 35 ms from 1.1 to 0.9 VLLs
Reset time < 35 ms from 0.9 to 1.1 VLLs
Inputs
Designation Syntax Equations Logipam
Protection reset P27R_x_101 b b
Protection blocking P27R_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P27R_x_1 b b
Delayed output P27R_x_3 b b b
Protection blocked P27R_x_16 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
Generator protection against insulation Due to their geometric characteristics, generators produce third-order harmonic
faults. This function should be combined voltages (VH3) in addition to the fundamental voltage. The amplitude of the VH3
voltage may vary from 0 to 10% of VN, as a function of:
with 59N or 51N to ensure 100% stator b network and generator characteristics
ground fault protection (64G). b the load on the generator. It is generally higher under full-load than under no-
load conditions.
In the absence of a fault, the VH3 voltage must be at least 0.2% of VN for protection
Description function 27TN.
This function protects generators against phase-to- VH3 Voltage with No Fault
ground insulation faults by detecting any reduction of the During normal operation, the VH3 voltage is measured at each end of the windings.
third harmonic residual voltage.This function protects 10
to 20% of the stator winding on the neutral point end.
DE51614
Complete protection of the stator winding is ensured by
combining this function with function 59N or 51N, which
protects 85 to 95% of the winding on the terminal end.
3
VH3 Voltage with a Fault on the Neutral Point End
When a single-phase fault occurs in the stator winding near the machine neutral
point, the neutral point impedance is short-circuited. This causes a drop in the H3
voltage on the neutral point end.
DE51615
The third harmonic undervoltage protection function detects the drop in the VH3
voltage caused by a single-phase fault on the neutral-point end.
Two types of tripping set points are available according to the VTs connected:
b fixed set point: tripping for VH3 neutral point undervoltage. The setting
requires preliminary measurements.
b adaptive set point: tripping for VH3 neutral point undervoltage depending on a
set point whose value depends on the VH3 residual voltage. The setting does
not require preliminary measurements.
Availability of Set Points Depending on the VTs Used
Voltage Measurements Available Types
VT Neutral Point VT Terminals 27TN Fixed Set Point 27TN Adaptive Set
Point
- All wiring - -
b Van or Vab - -
b Vab, Vbc b -
b Van, Vbn, Vcn b b
The protection function operates only if the neutral point VntH3 voltage before the
fault is greater than 0.2% of the network phase-to-neutral voltage.
The protection function is blocked if the power (S) produced by the generator is low
VLL
or if the positive sequence voltage (V1) is insufficient.
Adjustment
N.O. This function is adjusted according to a series of measurements on the neutral point
VntH3 voltage of the generator. These measurements are used to determine the
lowest VntH3 voltage value under normal operating conditions.
The measurements should be carried out:
b under no-load conditions, not connected to the network
b at a number of load levels because the H3 voltage level depends on the load
The parameter is set below the lowest H3 voltage value measured. The Sepam
unit provides the neutral point VntH3 voltage measurement to facilitate adjustment of
the protection function.
3
Block Diagram
DE51545
Characteristics
Settings
Type of Set Point
Setting range Fixed
Third Harmonic Voltage Set Point Vs
Setting range 0.2 to 20% of Vntp
Accuracy (1) 5% or 0.05 V of neutral point Vnts
Resolution 0.1%
Drop out/pick up ratio 105%
Time Delay
Setting range 0.5 to 300 s
Accuracy (1) 2% or from 10 ms to +25 ms
Resolution 10 ms or 1 digit
Advanced Settings
Ssmin Set Point
Setting range 1% to 90% of 3.VLLp.IB
Accuracy (1) 5%
Resolution 1%
Drop out/pick up ratio 105%
V1smin Positive Sequence Undervoltage Set Point
Setting range 50% to 100% of VLLp
Accuracy (1) 5%
Resolution 1%
Drop out/pick up ratio 105%
Characteristic Times (1)
Operation time typically 140 ms from 2 Vs to 0
Overshoot time < 65 ms
Reset time < 65 ms
Inputs
Designation Syntax Equations Logipam
Protection reset P27TN/64G2_x_101 b b
Protection blocking P27TN/64G2_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Tripping output P27TN/64G2_x_3 b b b
Protection blocked P27TN/64G2_x_16 b b
Instantaneous output P27TN/64G2_x_23 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
on the neutral point end. The protection function calculates the H3 residual voltage
using the three phase-to-neutral voltages. Use of the H3 residual voltage is the
means to adapt the tripping set point according to the normal H3 voltage level.
G Time-delayed definite time (DT) tripping occurs when:
K
Vnt H3 y ---------------------- V rH3 .
3V 3(1 K)
The protection function operates only if the neutral point H3 voltage before the fault
N.O. is greater than 0.2% of the network phase-to-neutral voltage and if the positive
sequence voltage is greater than 30% of the phase-to-neutral voltage.
Adjustment
This function does not require any particular measurements but, in certain cases, it
may be necessary to adjust the K setting.
The Sepam unit measures the neutral point H3 voltage V3nt and the H3 residual
voltage VrH3 to facilitate adjustment of the protection function.
3 b V3nt is expressed in % of the primary voltage of the neutral point VTs Vntp
b V3nt is expressed in % of the primary voltage of the terminal-side VTs VLnp.
If the primary voltages of the VTs are different, VntH3 must be adapted to the
terminal-side primary voltage Vnp using the equation:
Vntp
VntH3 (%VLnp) = V3nt (%Vntp) x ---------------- (See the table on the following page
V L np
Block Diagram
DE51546
V1
Characteristics
Settings
Type of Set Point
Setting range Adaptive
Time Delay
Setting range 0.5 to 300 s
Accuracy (1) 2% or from -10 ms to +25 ms
Resolution 10 ms or 1 digit
Advanced Settings
K Set Point
Setting range 0.1 to 0.2
Accuracy (1) 1%
Resolution 0.01
Drop out/pick up ratio 105%
Characteristic Times (1)
Operation time typically 140 ms (2)
Overshoot time < 65 ms
Reset time < 65 ms
Inputs
Designation Syntax Equations Logipam
Protection reset P27TN/64G2_x_101 b b
Protection blocking P27TN/64G2_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Tripping output P27TN/64G2_x_3 b b b
Protection blocked P27TN/64G2_x_16 b b
Instantaneous output P27TN/64G2_x_23 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
(2) Measured for a variation of 2V3nt to 0 with VrH3 = 30%.
K
Curves ---------------------- V 3 r
3(1 K)
K max = 0.2
K min = 0.1
Protection against reverse power and This protection function enables if the active power flowing in either direction
overloads. (supplied or drawn) is greater than set point Ps. It includes a definite time delay, T,
and is based on the two or three-wattmeter method of measurement, depending on
the connection conditions:
b Van, Vbn, Vcn, and Ia, Ib, Ic: three wattmeters
Description b Vab, Vbn, Vcn, and Ia, Ic: two wattmeters
Two-way protection based on calculated active power, b Vab, Vbc with Vr, and Ia, Ib, Ic: three wattmeters
for the following applications: b Vab, Vbc with Vr and Ia, Ic: two wattmeters
b active overpower protection to detect overloads b Vab, Vbc without Vr: two wattmeters
and allow load shedding b other cases: protection function unavailable.
b reverse active power protection: The function is enabled only if the following condition is met:
v against generators running like motors when P 3.1% Q
the generators draw active power This provides a high level of sensitivity and high stability in the event of short-circuits.
v against motors running like generators when The power sign is determined according to the general feeder or main parameter,
the motors supply active power. according to the convention:
For the feeder circuit:
b power supplied by the bus is positive
3
DE50769
b power supplied to the bus is negative
DE50771
DE50770
b power supplied by the busses is negative.
Block Diagram
DE50772
Operating zone
Characteristics
Settings
Tripping Direction
Setting range Overpower/reverse power
Ps Set Point
Setting range 1% of Sn (2) to 120% of Sn (2)
Accuracy (1) 0.3% Sn for Ps between 1% Sn and 5% Sn
5% for Ps between 5% Sn and 40% Sn
3% for Ps between 40% Sn and 120% Sn
Resolution 0.1 kW
Drop out/pick up ratio 93.5% 5% or > (1 - 0.004 Sn/Ps) x 100%
Time Delay T
Setting range 100 ms to 300 s
Accuracy (1) 2% or -10 ms to +25 ms
Resolution 10 ms or 1 digit
Characteristic Times
Operation time < 90 ms at 2 Ps
Overshoot time < 40 ms at 2 Ps
Reset time < 105 ms at 2 Ps
Inputs
Designation Syntax Equations Logipam
Protection reset P32P_x_101 b b
Protection blocking P32P_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P32P_x_1 b b
Delayed output P32P_x_3 b b b
Protection blocked P32P_x_16 b b
Positive active power P32P_x_19 b b
Negative active power P32P_x_20 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
(2) Sn = 3 VLL IN.
Protection against field loss on synchronous The protection function picks up if the reactive power (Q) flowing in one direction or
machines. the other (supplied or drawn) is greater than the set point for reactive power.
It includes a definite time delay, T, and is based on the two or three-wattmeter
method of measurement, depending on the connection conditions:
b Van, Vbn, Vcn, and Ia, Ib, Ic: three wattmeters
Description b Van, Vbn, Vcn and Ia, Ic: two wattmeters
This two-way protection is based on calculated reactive b Vab, Vbc with Vr, and Ia, Ib, Ic: three wattmeters
power to detect field loss on synchronous machines: b Vab, Vbc with Vr, and Ia, Ic: two wattmeters
b reactive overpower protection for motors that b Vab, Vbc without Vr: two wattmeters
consume more reactive power following field loss b other cases: protection function unavailable.
b reverse reactive overpower protection for The function is enabled only if the following condition is met:
generators that consume reactive power Q 3.1% P
following field loss. This provides a high level of sensitivity and high stability in the event of short-circuits.
The power sign is determined according to the general feeder or main parameter,
according to the convention:
For the feeder circuit:
b power supplied by the busses is positive
3
DE50769
b power supplied to the bus is negative
DE50773
DE50770
b power supplied by the busses is negative.
Block Diagram
DE50774
Characteristics
Settings
Tripping Direction
Setting range Overpower/reverse power
Qs Set Point
Setting range 5% of Sn (2) to 120% of Sn (2)
Accuracy (1) 5% for Qs between 5% Sn and 40% Sn
Operating zone. 3% for Qs between 40% Sn and 120% Sn
Resolution 0.1 kW
Drop out/pick up ratio 93.5%
Time Delay T
Setting range 100 ms to 300 s
Accuracy (1) 2% or -10 ms to +25 ms
Resolution 10 ms or 1 digit
Characteristic Times
Operation time < 90 ms
Overshoot time < 95 ms
Reset time < 90 ms
Inputs
Designation Syntax Equations Logipam
Protection reset P32Q_1_101 b b
Protection blocking P32Q_1_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P32Q_1_1 b b
Delayed output P32Q_1_3 b b b
Protection blocked P32Q_1_16 b b
Positive reactive power P32Q_1_54 b b
Negative reactive power P32Q_1_55 b b
(1) Under reference conditions (IEC 60255-6).
(2) Sn = 3 VLL IN.
Protection for pumps. This protection is single-phase. It enables when phase "a" current (Ia) drops below
its set point (Is).
Description
DE50775
This function protects pumps against the results of a
0.015 IB
loss of priming by detecting motor no-load operations.
Current sag.
This protection is inactive when the current is less than 1.5% of IN. It is insensitive
to current drops due to circuit breaker tripping.
DE50776
3 0.015 IB
Block Diagram
DE50777
I > 0.015 IN
Characteristics
Settings
Is Set Point
Setting range 5% Ib to 100% IB
Accuracy (1) 5%
Resolution 1%
Drop out/pick up ratio 106%
Time Delay T
Setting range 50 ms to 300 s
Accuracy (1) 2% or 25 ms
Resolution 10 ms or 1 digit
Characteristic Times
Operation time pick-up < 50 ms
Overshoot time < 40 ms
Reset time < 40 ms
Inputs
Designation Syntax Equations Logipam
Protection reset P37_1_101 b b
Protection blocking P37_1_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P37_1_1 b b
Delayed output P37_1_3 b b b
Protection blocked P37_1_16 b b
(1) Under reference conditions (IEC 60255-6).
The protection function enables if the active power flowing in one direction or the
other (supplied or drawn) is less than the power set point, Ps.
It includes a definite time delay, T,. and is based on the two or three-wattmeter
method of measurement, depending on the connection conditions:
b Van, Vbn, Vcn, and Ia, Ib, Ic: three wattmeters
b Van, Vbn, Vcn, and Ia, Ic: two wattmeters
b Vab, Vbc with Vr, and Ia, Ib, Ic: three wattmeters
Tripping zone (normal direction). b Vab, Vbc with Vr, and Ia, Ic: two wattmeters
b Vab, Vbc without Vr: two wattmeters
b other cases: protection function unavailable.
3
DE51383
The power sign is determined according to the general feeder or Main parameter,
according to the convention:
For the feeder circuit:
b power supplied by the bus is positive (normal direction)
DE50769
b power supplied to the bus is negative
DE50770
b power supplied by the bus is negative.
Tripping zone (reverse direction).
Block Diagram
DE50824
Characteristics
Settings
Tripping Direction
Setting range Normal / reverse
Ps Set Point
Setting range 5% of Sn (2) to 100% of Sn (2)
Accuracy (1) 5% for Ps between 5% Sn and 40% Sn
3% for Ps between 40% Sn and 120% Sn
Resolution 0.1 kW
Drop out/pick up ratio 106%
Time Delay T
Setting range 100 ms to 300 s
Accuracy (1) 2% or -10 ms to +25 ms
Resolution 10 ms or 1 digit
Characteristic Times
Operation time < 120 ms
Overshoot time < 65 ms
Reset time < 60 ms
Inputs
Designation Syntax Equations Logipam
Protection reset P37P_x_101 b b
Protection blocking P37P_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P37P_x_1 b b
Delayed output P37P_x_3 b b b
Protection blocked P37P_x_16 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
(2) Sn = 3.VLL IN.
When the protection function is activated, it detects whether the RTD is shorted or
disconnected:
b RTD shorting is detected if the measured temperature is less than 31 F or
3 35 C (measurement displayed "****")
b RTD disconnection is detected if the measured temperature is greater than
+205 C or +401 F (measurement displayed "-****").
If an RTD fault is detected, the protection function is blocked and its output relays are
set to zero. The "RTD fault" item is also made available in the control matrix and an
alarm message is generated specifying the number of the MET1482 module for the
faulty RTD.
Block Diagram
DE50778
Characteristics
Settings
Alarm and Trip Set Points TS1, TS2
Setting range 0C to 180C 32F to 356F
Accuracy (1) 1.5C 2.7F
Resolution 1C 1F
Pick up / drop out difference 3C 5.4F
Inputs
Designation Syntax Equations Logipam
Protection reset P38/49T_x_101 b b
Protection blocking P38/49T_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Protection output P38/49T_x_3 b b b
Alarm P38/49T_x_10 b b b
RTD fault P38/49T_x_12 b b
Protection blocked P38/49T_x_16 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
V1
Z 1 = -------
I 1
DE50306
Block Diagram
DE50825
3 V LL 1
Z N = ----------------
3I B
.
Characteristics
Settings
Common Point: Xa
Setting range 0.02VN/IB Xa 0.20VN/IB + 187.5 k or 0.001
Accuracy (1) 5%
Resolution 1%
Circle 1: Xb
Setting range 0.20VN/IB Xa 1.40VN/IB + 187.5 k
Accuracy (1) 5%
Resolution 0.001 or 1 digit
Drop out/pick up ratio 105% of circle 1 diameter
Circle 2: Xc
Setting range 0.60VN/IB Xa 3VN/IB + 187.5 k
Accuracy (1) 5%
Resolution 0.001 or 1 digit
Drop out/pick up ratio 105% of circle 2 diameter
T1 Time: Tripping Time Delay Circle 1
Setting range 50 ms T 300 s
Accuracy (1) 2% or from 10 ms to +25 ms
Resolution 10 ms or 1 digit
T2 time: Tripping Time Delay Circle 2
Setting range 100 ms T 300 s
Accuracy (1) 2% or from 10 ms to +25 ms
Resolution 10 ms or 1 digit
Characteristic Times (1)
Operation time Pick-up < 35 ms from 0 to C1 (typically 25 ms)
Pick-up < 35 ms from 0 to C2 (typically 25 ms)
Overshoot time < 40 ms
Reset time < 50 ms (for T1 = 0)
Inputs
Designation Syntax Equations Logipam
Protection reset P40_1_101 b b
Protection blocking P40_1_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P40_1_1 b b
Delayed output P40_1_3 b b b
Protection blocked P40_1_16 b b
Instantaneous protection 1 (circle 1) P40_1_23 b b
(1) Under reference conditions (IEC 60255-6).
2 2
Xt x = Zt x Rt x = 0.929
.
Circle 1 is set with a diameter Zn, offset by -X'd/2 and the transformer reactance.
Circle 2 is set with a diameter Xd, offset by -X'd/2 and the transformer reactance.
b Xa = (X'd(%)/200)ZN + X_tx = 4.09
b Xb = (X'd(%)/200 + 1)ZN + X_tx = 24.2
b Xc = (X'd(%)/200 + X1(%)/100)ZN + X_tx = 57.1 .
The faults detected in circle 1 are violent field-loss faults that must be cleared rapidly.
Circle 2 may concern faults other than field-loss faults and its tripping time is longer:
b T1 = 70 ms
b T2 = 500 ms.
The time delay may be definite time or IDMT, according to a standardized curve, a
specially adapted Schneider curve, or an I2R curve for generator protection.
Tripping Curve
Schneider IDMT
IEC inverse time SIT / A
IEC very inverse time VIT or LTI / B
Block Diagram
DE50839
Characteristics
Settings
Measurement Origin
Setting range Main channels (I)
Additional channels (I)
Tripping Curve
Setting range See list above
Is Set Point
Setting range definite time 10% to 500% of IB or I'B
Schneider IDMT 10% to 50% of IB or I'B
IEC or IEEE IDMT 10% to 100% of IB or I'B
I2R curve 3% to 20% of IB or I'B
Accuracy (1) 5% or 0.004 IN
Resolution 1%
Drop out/pick up ratio 93.5% 5% or > (1 - 0.005 IN/Is) x 100%
Time Delay T
Setting range definite time 100 ms T 300 s
IDMT 100 ms T 1 s or TMS (2)
Accuracy (1) definite time 2% or +25 ms
IDMT 5% or +35 ms
Resolution 10 ms or 1 digit
K (I22t Curve Only)
Setting range 1 to 100
Resolution 1
Characteristic Times
Operation time Pick-up < 55 ms at 2 Is
Overshoot time < 50 ms at 2 Is
Reset time < 55 ms at 2 Is
Inputs
x: unit number. Designation Syntax Equations Logipam
(1) Under reference conditions (IEC 60255-6).
(2) Setting ranges in TMS (Time Multiplier Setting) mode: Protection reset P46_x_101 b b
Inverse (SIT) and IEC SIT/A: 0.034 to 0.336 Protection blocking P46_x_113 b b
Very inverse (VIT) and IEC VIT/B: 0.067 to 0.666 Outputs
Very inverse (LTI) and IEC LTI/B: 0.008 to 0.075
Designation Syntax Equations Logipam Matrix
Ext. inverse (EIT) and IEC EIT/C: 0.124 to 1.237
IEEE moderately inverse : 0.415 to 4.142 Instantaneous output (pick-up) P46_x_1 b b
IEEE very inverse : 0.726 to 7.255 Delayed output P46_x_3 b b b
IEEE extremely inverse : 1.231 to 12.30. Protection blocked P46_x_16 b b
basis. The continuous level (Is), indicated by the manufacturer, is generally between
5 and 10% of the base current IB.
Typical values are:
Type of Generator I2 permissible (% Ib)
Salient poles with amortisseur windings 10
without amortisseur windings 5
I1 Cylindrical rotors Indirectly cooled 10
IB 5 IB Sn 960 MVA 8
960 MVA < Sn 1200 MVA 6
2t
I2 curve. 1200 MVA < Sn 5
Reference IEEE C37.102-1987.
When this current level is exceeded, the generator can handle a negative sequence
current I2 for a time td, corresponding to the following equation:
K
td = --------------------2-
------------
I 2
3
-
IB
4.64
-T
t = ---------------------------
0.96
(I2 IB)
100
3 50
20
max. curve (T=1s)
10
0.5
0.2
0,1
0.02
0.01
0.005
0.002
0.001 I/IB
l2 (% lB) cont. 80 85 90 95 100 110 120 130 140 150 160 170 180 190 200 210
X cont. 5.74 5.42 5.13 4.87 4.64 4.24 3.90 3.61 3.37 3.15 2.96 2.80 2.65 2.52 2.40 2.29
l2 (% lB) cont. 220 230 240 250 260 270 280 290 300 310 320 330 340 350 360 370
X cont. 2.14 2.10 2.01 1.94 1.86 1.80 1.74 1.68 1.627 1.577 1.53 1.485 1.444 1.404 1.367 1.332
l2 (% lB) cont. 380 390 400 410 420 430 440 450 460 470 480 490 u 500
X cont. 1.298 1.267 1.236 1.18 1.167 1.154 1.13 1.105 1.082 1.06 1.04 1.02 1
Block Diagram
DE50779
Characteristics
Settings
Measurement Origin
Setting range
Vs2 Set Point
Main channels (VLL) / Additional channels (VLL)
3
Setting range 1% to 50% of VLLNp
Accuracy (1) 2% or 0.005 VLLNp
Resolution 1%
Drop out/pick up ratio 97% 1% or > (1 - 0.006 VLLNp/Vs2) x 100%
Time Delay T
Setting range 50 ms to 300 s
Accuracy (1) 2% or 25 ms
Resolution 10 ms or 1 digit
Characteristic Times
Operation time Pick-up < 40 ms at 2 Vs2
Overshoot time < 50 ms at 2 Vs2
Reset time < 50 ms at 2 Vs2
Inputs
Designation Syntax Equations Logipam
Protection reset P47_x_101 b b
Protection blocking P47_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P47_x_1 b b
Delayed output P47_x_3 b b b
Protection blocked P47_x_16 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
3 Case of normal starting. The ST time delay (which corresponds to the normal starting time) can be
reinitialised by the logic input "motor re-acceleration."
This will reinitialize the excessive starting time protection and set the locked rotor
DE50827
0.05 IB
0.05 IB
0.05 IB
Characteristics
Settings
Is Set Point
Setting range 50% to 500% of IB
Accuracy (1) 5%
Resolution 1%
Drop out/pick up ratio 93%
Time Delay T
Setting range ST 500 ms to 300 s
LT 50 ms to 300 s
LTS 50 ms to 300 s
Accuracy (1) 2% or 25 ms
Resolution 10 ms
Inputs
Designation Syntax Equations Logipam
Protection reset P48/51LR_1_101 b b
Motor re-acceleration P48/51LR_1_102 b b
Protection blocking
Outputs
P48/51LR_1_113 b b
3
Designation Syntax Equations Logipam Matrix
Protection output P48/51LR_1_3 b b b
Locked rotor P48/51LR_1_13 b b b
Excessive starting time P48/51LR_1_14 b b b
Locked rotor at start-up P48/51LR_1_15 b b b
Protection blocked P48/51LR_1_16 b b
Starting in progress P48/51LR_1_22 b b
(1) Under reference conditions (IEC 60255-6).
Iph = max ( I a, I b, I c ) .
The calculated heat rise, proportional to the square of the current drawn, depends on
the current drawn and the previous temperature status. Under steady-state
conditions, it is equal to:
Iph 2
E = --------- 100 in%
IB
The protection function issues the trip command when the phase current is greater
than the permissible current for the cable. The value of the base current IB must
3 Tripping curves.
absolutely be less than the permissible current Ia. By default, we use IB Ia/1.4.
The protection tripping time is set by the time constant T.
I 2
----- -
t IB
Cold curve: --- = I N --------------------------------------
2 2
where lN: natural logarithm.
T ------ ------
I Ia
IB IB
----- - 1
I 2
t IB
Hot curve: --- = I N -------------------------------------- where lN: natural logarithm.
T I 2 Ia 2
----- - ------
IB IB
The present heat rise is saved in the event of an auxiliary power failure.
Block Diagram
DE51549
User Information
The following information is available for the user:
b heat rise
b time before tripping (with constant current).
Characteristics
Settings
Permissible Current Ia
Setting range < 1 to 1.73 IB
Accuracy (1) 2%
Resolution 1A
Time Constant T
Setting range 1 min. to 600 min.
Resolution 1 min.
Characteristic Times (1)
Operation time accuracy 2% or 1 s
Inputs
Designation Syntax Equations Logipam
Protection reset P49RMS_1_101 b b
Protection blocking P49RMS_1_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Delayed output P49RMS_1_3 b b b
Alarm P49RMS_1_10 b b b
Block closing P49RMS_1_11 b b b
Protection blocked P49RMS_1_16 b b
Hot state P49RMS_1_18 b b
Block thermal overload P49RMS_1_32 b b
(1) Under reference conditions (IEC 60255-6).
Example
Consider a copper cable, 350MCM, with a permissible current Ia = 485 A and a
DE50840
The thermal time constant of a cable depends on its installation method. Typical
time-constant values are between 10 and 60 minutes. For buried cables, the time
constant is between 20 and 60 minutes, for non-buried cables, it is between 10 and
40 minutes.
For the cable in question, the selected values are T = 30 minutes and IB = 350 A.
Cable thermal Check compatibility between the 49RMS curve and the cable thermal
withstand withstand curve.
In the range of currents close to the permissible current, the 1-second thermal
IB IB withstand is used to estimate maximum thermal withstand for the cable, assuming
there are no heat exchanges. The maximum tripping time is calculated as: 3
I2 x tmax = constant = (Ith_1 s)2 x 1.
For I = 10 IB = 3500 A and Ia/IB = 1.38, the value of k in the cold tripping curve table
is k 0.0184.
For a 10 IB fault occuring after a rated operation phase, with 100% heat rise, the
value of k is : k 0.0097.
t = k x T x 60 = 0.0097 x 30 x 60 = 17.5 s
Coordination Check
Coordination between 49RMS for the cable and the downstream protection curves
(including 49RMS Protection Functions) must be checked to avoid any risk of
nuisance tripping.
3 1.10
1.15
1.20
2.4643 1.8343
2.5060
1.4890
1.8734
2.5459
1.2587
1.5258
1.9110
1.25 2.5844
Iph/IB 1.35 1.40 1.45 1.50 1.55 1.60 1.65 1.70 1.75 1.80 1.85 1.90 1.95 2.00 2.20 2.40
Ia/IB
0.50 0.1475 0.1365 0.1266 0.1178 0.1099 0.1028 0.0963 0.0905 0.0852 0.0803 0.0759 0.0718 0.0680 0.0645 0.0530 0.0444
0.55 0.1815 0.1676 0.1553 0.1444 0.1346 0.1258 0.1178 0.1106 0.1040 0.0980 0.0925 0.0875 0.0829 0.0786 0.0645 0.0539
0.60 0.2201 0.2029 0.1878 0.1744 0.1623 0.1516 0.1418 0.1330 0.1251 0.1178 0.1111 0.1051 0.0995 0.0943 0.0773 0.0645
0.65 0.2637 0.2428 0.2243 0.2080 0.1934 0.1804 0.1686 0.1581 0.1485 0.1397 0.1318 0.1245 0.1178 0.1116 0.0913 0.0762
0.70 0.3132 0.2877 0.2653 0.2456 0.2281 0.2125 0.1984 0.1858 0.1744 0.1640 0.1545 0.1459 0.1380 0.1307 0.1067 0.0889
0.75 0.3691 0.3383 0.3113 0.2877 0.2667 0.2481 0.2314 0.2165 0.2029 0.1907 0.1796 0.1694 0.1601 0.1516 0.1236 0.1028
0.80 0.4326 0.3953 0.3630 0.3347 0.3098 0.2877 0.2680 0.2503 0.2344 0.2201 0.2070 0.1952 0.1843 0.1744 0.1418 0.1178
0.85 0.5049 0.4599 0.4210 0.3873 0.3577 0.3316 0.3084 0.2877 0.2691 0.2523 0.2371 0.2233 0.2107 0.1992 0.1617 0.1340
0.90 0.5878 0.5332 0.4866 0.4463 0.4112 0.3804 0.3531 0.3289 0.3072 0.2877 0.2701 0.2541 0.2396 0.2263 0.1832 0.1516
0.95 0.6836 0.6170 0.5608 0.5127 0.4710 0.4347 0.4027 0.3744 0.3491 0.3265 0.3061 0.2877 0.2710 0.2557 0.2064 0.1704
1.00 0.7956 0.7138 0.6456 0.5878 0.5383 0.4953 0.4578 0.4247 0.3953 0.3691 0.3456 0.3244 0.3052 0.2877 0.2314 0.1907
1.05 0.9287 0.8267 0.7431 0.6733 0.6142 0.5633 0.5191 0.4804 0.4463 0.4159 0.3888 0.3644 0.3424 0.3225 0.2585 0.2125
1.10 1.0904 0.9606 0.8569 0.7717 0.7005 0.6399 0.5878 0.5425 0.5027 0.4675 0.4363 0.4082 0.3830 0.3603 0.2877 0.2358
1.15 1.2934 1.1231 0.9916 0.8862 0.7996 0.7269 0.6651 0.6118 0.5654 0.5246 0.4884 0.4563 0.4274 0.4014 0.3192 0.2609
1.20 1.5612 1.3269 1.1549 1.0217 0.9147 0.8267 0.7527 0.6897 0.6353 0.5878 0.5460 0.5090 0.4759 0.4463 0.3531 0.2877
1.25 1.9473 1.5955 1.3593 1.1856 1.0509 0.9425 0.8531 0.7780 0.7138 0.6583 0.6098 0.5671 0.5292 0.4953 0.3898 0.3165
1.30 2.6214 1.9823 1.6286 1.3907 1.2155 1.0793 0.9696 0.8789 0.8026 0.7373 0.6808 0.6314 0.5878 0.5491 0.4295 0.3473
1.35 2.6571 2.0161 1.6607 1.4212 1.2445 1.1069 0.9959 0.9041 0.8267 0.7604 0.7029 0.6526 0.6081 0.4725 0.3804
1.40 2.6915 2.0488 1.6918 1.4508 1.2727 1.1338 1.0217 0.9287 0.8502 0.7829 0.7245 0.6733 0.5191 0.4159
1.45 2.7249 2.0805 1.7220 1.4796 1.3001 1.1601 1.0467 0.9527 0.8733 0.8050 0.7458 0.5699 0.4542
1.50 2.7571 2.1112 1.7513 1.5075 1.3269 1.1856 1.0712 0.9762 0.8958 0.8267 0.6253 0.4953
1.55 2.7883 2.1410 1.7797 1.5347 1.3529 1.2106 1.0952 0.9992 0.9179 0.6859 0.5397
1.60 2.8186 2.1699 1.8074 1.5612 1.3783 1.2349 1.1185 1.0217 0.7527 0.5878
1.65 2.8480 2.1980 1.8343 1.5870 1.4031 1.2587 1.1414 0.8267 0.6399
1.70 2.8766 2.2254 1.8605 1.6122 1.4272 1.2819 0.9091 0.6966
Iph/IB 7.00 7.50 8.00 8.50 9.00 9.50 10.00 12.50 15.00 17.50 20.00
Ia/IB
0.50 0.0051 0.0045 0.0039 0.0035 0.0031 0.0028 0.0025 0.0016 0.0011 0.0008 0.0006
0.55 0.0062 0.0054 0.0047 0.0042 0.0037 0.0034 0.0030 0.0019 0.0013 0.0010 0.0008
0.60 0.0074 0.0064 0.0056 0.0050 0.0045 0.0040 0.0036 0.0023 0.0016 0.0012 0.0009
0.65 0.0087 0.0075 0.0066 0.0059 0.0052 0.0047 0.0042 0.0027 0.0019 0.0014 0.0011
0.70 0.0101 0.0087 0.0077 0.0068 0.0061 0.0054 0.0049 0.0031 0.0022 0.0016 0.0012
0.75 0.0115 0.0101 0.0088 0.0078 0.0070 0.0063 0.0056 0.0036 0.0025 0.0018 0.0014
0.80 0.0131 0.0114 0.0101 0.0089 0.0079 0.0071 0.0064 0.0041 0.0028 0.0021 0.0016
0.85 0.0149 0.0129 0.0114 0.0101 0.0090 0.0080 0.0073 0.0046 0.0032 0.0024 0.0018
0.90 0.0167 0.0145 0.0127 0.0113 0.0101 0.0090 0.0081 0.0052 0.0036 0.0026 0.0020
0.95 0.0186 0.0162 0.0142 0.0126 0.0112 0.0101 0.0091 0.0058 0.0040 0.0030 0.0023
1.00 0.0206 0.0179 0.0157 0.0139 0.0124 0.0111 0.0101 0.0064 0.0045 0.0033 0.0025
1.05 0.0228 0.0198 0.0174 0.0154 0.0137 0.0123 0.0111 0.0071 0.0049 0.0036 0.0028
1.10 0.0250 0.0217 0.0191 0.0169 0.0151 0.0135 0.0122 0.0078 0.0054 0.0040 0.0030
1.15 0.0274 0.0238 0.0209 0.0185 0.0165 0.0148 0.0133 0.0085 0.0059 0.0043 0.0033
1.20 0.0298 0.0259 0.0228 0.0201 0.0179 0.0161 0.0145 0.0093 0.0064 0.0047 0.0036
1.25 0.0324 0.0282 0.0247 0.0219 0.0195 0.0175 0.0157 0.0101 0.0070 0.0051 0.0039
1.30 0.0351 0.0305 0.0268 0.0237 0.0211 0.0189 0.0170 0.0109 0.0075 0.0055 0.0042
1.35 0.0379 0.0329 0.0289 0.0255 0.0228 0.0204 0.0184 0.0117 0.0081 0.0060 0.0046
1.40 0.0408 0.0355 0.0311 0.0275 0.0245 0.0220 0.0198 0.0126 0.0087 0.0064 0.0049
1.45 0.0439 0.0381 0.0334 0.0295 0.0263 0.0236 0.0212 0.0135 0.0094 0.0069 0.0053
1.50 0.0470 0.0408 0.0358 0.0316 0.0282 0.0252 0.0228 0.0145 0.0101 0.0074 0.0056
1.55 0.0503 0.0437 0.0383 0.0338 0.0301 0.0270 0.0243 0.0155 0.0107 0.0079 0.0060
1.60 0.0537 0.0466 0.0408 0.0361 0.0321 0.0288 0.0259 0.0165 0.0114 0.0084 0.0064
1.65 0.0572 0.0496 0.0435 0.0384 0.0342 0.0306 0.0276 0.0176 0.0122 0.0089 0.0068
1.70 0.0608 0.0527 0.0462 0.0408 0.0363 0.0325 0.0293 0.0187 0.0129 0.0095 0.0073
Iph/IB 1.95 2.00 2.20 2.40 2.60 2.80 3.00 3.20 3.40 3.60 3.80 4.00 4.20 4.40 4.60 4.80
Ia/IB
1.10 0.0779 0.0726 0.0562 0.0451 0.0371 0.0312 0.0266 0.0230 0.0201 0.0177 0.0157 0.0141 0.0127 0.0115 0.0105 0.0096
1.15 0.1223 0.1137 0.0877 0.0702 0.0576 0.0483 0.0411 0.0355 0.0310 0.0273 0.0243 0.0217 0.0196 0.0177 0.0161 0.0147
1.20 0.1708 0.1586 0.1217 0.0970 0.0795 0.0665 0.0566 0.0488 0.0426 0.0375 0.0333 0.0298 0.0268 0.0243 0.0221 0.0202
1.25 0.2240 0.2076 0.1584 0.1258 0.1028 0.0858 0.0729 0.0628 0.0547 0.0482 0.0428 0.0382 0.0344 0.0311 0.0283 0.0259
1.30 0.2826 0.2614 0.1981 0.1566 0.1276 0.1063 0.0902 0.0776 0.0676 0.0594 0.0527 0.0471 0.0424 0.0383 0.0348 0.0318
1.35 0.3474 0.3204 0.2410 0.1897 0.1541 0.1281 0.1085 0.0932 0.0811 0.0713 0.0632 0.0564 0.0507 0.0458 0.0417 0.0380
1.40 0.4194 0.3857 0.2877 0.2253 0.1823 0.1512 0.1278 0.1097 0.0953 0.0837 0.0741 0.0661 0.0594 0.0537 0.0488 0.0445
1.45 0.4999 0.4581 0.3384 0.2635 0.2125 0.1758 0.1483 0.1271 0.1103 0.0967 0.0856 0.0763 0.0686 0.0619 0.0562 0.0513
1.50 0.5907 0.5390 0.3938 0.3046 0.2446 0.2018 0.1699 0.1454 0.1260 0.1104 0.0976 0.0870 0.0781 0.0705 0.0640 0.0584
1.55 0.6940 0.6302 0.4545 0.3491 0.2790 0.2295 0.1928 0.1646 0.1425 0.1247 0.1102 0.0982 0.0881 0.0795 0.0721 0.0657
1.60 0.8134 0.7340 0.5213 0.3971 0.3159 0.2589 0.2169 0.1849 0.1599 0.1398 0.1234 0.1098 0.0984 0.0888 0.0805 0.0734
1.65 0.9536 0.8537 0.5952 0.4492 0.3553 0.2901 0.2425 0.2063 0.1781 0.1555 0.1372 0.1220 0.1093 0.0985 0.0893 0.0814
1.70 1.1221 0.9943 0.6776 0.5059 0.3977 0.3234 0.2695 0.2288 0.1972 0.1720 0.1516 0.1347 0.1206 0.1086 0.0984 0.0897
Iph/IB 5.00 5.50 6.00 6.50 7.00 7.50 8.00 8.50 9.00 9.50 10.00 12.50 15.00 17.50 20.00
Ia/IB
1.10 0.0088 0.0072 0.0060 0.0051 0.0044 0.0038 0.0033 0.0030 0.0026 0.0024 0.0021 0.0014 0.0009 0.0007 0.0005
1.15 0.0135 0.0111 0.0093 0.0078 0.0067 0.0059 0.0051 0.0045 0.0040 0.0036 0.0033 0.0021 0.0014 0.0011 0.0008
1.20 0.0185 0.0152 0.0127 0.0107 0.0092 0.0080 0.0070 0.0062 0.0055 0.0049 0.0045 0.0028 0.0020 0.0014 0.0011
1.25 0.0237 0.0194 0.0162 0.0137 0.0118 0.0102 0.0090 0.0079 0.0071 0.0063 0.0057 0.0036 0.0025 0.0018 0.0014
1.30 0.0292 0.0239 0.0199 0.0169 0.0145 0.0126 0.0110 0.0097 0.0087 0.0078 0.0070 0.0045 0.0031 0.0023 0.0017
1.35 0.0349 0.0285 0.0238 0.0201 0.0173 0.0150 0.0131 0.0116 0.0103 0.0093 0.0083 0.0053 0.0037 0.0027 0.0021
1.40 0.0408 0.0334 0.0278 0.0235 0.0202 0.0175 0.0154 0.0136 0.0121 0.0108 0.0097 0.0062 0.0043 0.0031 0.0024
1.45 0.0470 0.0384 0.0320 0.0271 0.0232 0.0202 0.0177 0.0156 0.0139 0.0124 0.0112 0.0071 0.0049 0.0036 0.0028
1.50 0.0535 0.0437 0.0364 0.0308 0.0264 0.0229 0.0200 0.0177 0.0157 0.0141 0.0127 0.0081 0.0056 0.0041 0.0031
1.55 0.0602 0.0491 0.0409 0.0346 0.0297 0.0257 0.0225 0.0199 0.0177 0.0158 0.0143 0.0091 0.0063 0.0046 0.0035
1.60 0.0672 0.0548 0.0456 0.0386 0.0330 0.0286 0.0251 0.0221 0.0197 0.0176 0.0159 0.0101 0.0070 0.0051 0.0039
1.65 0.0745 0.0607 0.0505 0.0427 0.0365 0.0317 0.0277 0.0245 0.0218 0.0195 0.0176 0.0112 0.0077 0.0057 0.0043
1.70 0.0820 0.0668 0.0555 0.0469 0.0402 0.0348 0.0305 0.0269 0.0239 0.0214 0.0193 0.0122 0.0085 0.0062 0.0047
The current measured by the thermal protection is an RMS 3-phase current that
100
factors harmonics up to the13th.
10-1 The highest current of the three phases Ia, Ib, and Ic, subsequently called phase
current Iph, is used to calculate the heat rise:
10-2
Iph = max ( I a ,I b ,I c )
-3
10 Taking capacitor step ratio into account
0 5 10
When the number of steps (>1) and capacitor step ratio are set in the particular
Tripping curves.
characteristics, the thermal overload protection function takes into account the
participation of each step in the calculation of heat rise.
The rated current of step x (IBgx) is equal to the fraction of current that the step
represents in relation to the rated current of the capacitor bank (IB). 3
Kgx
I B gx = --------------------------- I B
n
Kgx
x=1
where IB is the rated current of the capacitor bank
x is the step number
n is the total number of steps, between 2 and 4
Kgx is the capacitor step ratio value of step x
The rated current of the sequence of steps (IBseq) is calculated. It is the sum of the
rated currents (IBgx) of the steps closed during the sequence.
n
I B seq = p ( x )I B gx
x=1
where x is the step number
n is the total number of steps, between 2 and 4
p(x) is the position of the step x:
b p(x) = 1 when the step switch x is closed
b p(x) = 0 when the step switch x is open.
The heat rise is proportional to the square of the current in relation to the rated current
of the sequence. Under steady state conditions, it is equal to:
E = ----------------- 100
Iph 2 as a%
Ibseq
If the closed positions of the steps are not acquired or if the number of steps set in the
particular characteristics is 1, the rated current of the sequences is equal to the rated
current of the capacitor bank. In such cases, the heat rise is proportional to the drawn
current in relation to the rated current of the capacitor bank. Under steady state
conditions, it is equal to:
E = --------- 100
Iph 2
as a%
Ib
Operation curve
The protection function gives a trip command when the current drawn is greater than
the overload current, with respect to the rated current of the sequence.
Tripping time is set by assigning a hot tripping time to a setting current. This setting
is used to calculate a time factor:
1
C = -------------------------------------------------
----- - 1
Is 2
I B where In: natural logarithm.
I N -------------------------------------
------ -------------
Is 2 Itrip 2
I B I B
The tripping time with an initial heat rise of 0% is then given by:
-----------------
Iph 2
-
I B seq
t = C In -------------------------------------------------------- Ts
3 Iph 2 Itrip 2
-----------------
Ibseq Ibseq -----------------
where In: natural logarithm.
= k x Ts
The tripping time with an intial heat rise of 100% is then given by:
----------------
Iph 2
-
Ibseq 1
t = C In -------------------------------------------------------- Ts where In: natural logarithm.
Iph 2 Itrip 2
----------------
Ibseq- ---------------- Ibseq
-
= k x Ts
The tripping curve tables give the values of k for an inital heat rise from 0% to 100%.
The current heat rise is saved in the event of an auxiliary power failure.
Block Diagram
DE51555
User Information
The following information is available for the user:
b heat rise
b time before tripping (with constant current).
Characteristics
Settings
Alarm Current Ialarm
Setting range 1.05 to 1.70 IB
Accuracy (1) 2%
Resolution 1A
Tripping Current Itrip
Setting range 1.05 to 1.70 IB
Accuracy (1) 2%
Resolution 1A
Setting Current Is
Setting range
Accuracy (1)
Resolution
1.02 Itrip to 2 IB
2%
1A
3
Setting Time Ts
Setting range 1 to 2000 minutes (range varies depending on the tripping and
setting currents)
Resolution 1 mn
Characteristic Times
Operation time accuracy 2% or 2 s
Inputs
Designation Syntax Equations Logipam
Protection reset P49RMS_1_101 b b
Protection blocking P49RMS_1_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Delayed output P49RMS _1_3 b b b
Alarm P49RMS _1_10 b b b
Block closing P49RMS _1_11 b b b
Protection blocked P49RMS _1_16 b b
Hot state P49RMS _1_18 b b
(1) Under reference conditions (IEC 60255-6).
Example
Given a 350 kVAR capacitor bank with three steps, and no harmonic filters, for a
PE50424
According to the manufacturer data, this capacitor bank can operate continuously with
an overload current of 120% IB and for 20 minutes with an overload of 140% IB.
3 Steps 1 and 2 are closed in the sequence in progress. The sequence current is:
1+2+0
I B seq = ----------------------- I B = 61 A
1+2+2
For a current of 125% IBseq = 76 A, and an initial heat rise of 100%, the value of k
in the tripping curve tables is: k = 2.486.
For a current of 140% IBseq = 141 A, and an initial heat rise of 0%, the value of k in
the tripping curve tables is: k = 2.164.
The table below summarizes the rated sequence current, the tripping current and
examples of tripping times for overload currents of 125% IB and 140% IB, for initial
heat rises of 0% and 100%.
+0+0
---------------------- IB = 20
+2+2
b b - 73 76 83 50 85 43 20
+2+0
---------------------- IB = 61
+2+2
- b b 97 101 83 50 113 43 20
0+2+2
---------------------- IB = 81
+2+2
Is = 1.2 IB
Iph/IBseq 1.85 1.90 1.95 2.00 2.20 2.40 2.60 2.80 3.00 3.20 3.40 3.60 3.80 4.00
Itrip/IBseq
1.05 1.4660 1.3741 1.2911 1.2158 0.9747 0.8011 0.6713 0.5714 0.4927 0.4295 0.3779 0.3352 0.2995 0.2692
1.10 0.6725 0.6293 0.5905 0.5554 0.4435 0.3635 0.3040 0.2584 0.2226 0.1939 0.1704 0.1511 0.1349 0.1212
1.15 0.3699 0.3456 0.3237 0.3040 0.2417 0.1976 0.1649 0.1399 0.1204 0.1047 0.0920 0.0815 0.0728 0.0653
3 Is = 1.3 IB
Iph/IBseq 1.10 1.15 1.20 1.25 1.30 1.35 1.40 1.45 1.50 1.55 1.60 1.65 1.70 1.75 1.80
Itrip/IBseq
1.05 15.0540 11.1530 9.0217 7.6039 6.5703 5.7750 5.1405 4.6210 4.1871 3.8189 3.5027 3.2281 2.9875 2.7752 2.5864
1.10 6.7905 5.0545 4.1030 3.4684 3.0047 2.6470 2.3611 2.1265 1.9301 1.7633 1.6197 1.4948 1.3852 1.2883
1.15 3.9779 2.9738 2.4220 2.0530 1.7829 1.5740 1.4067 1.2692 1.1539 1.0557 0.9711 0.8974 0.8327
1.20 2.5077 1.8824 1.5378 1.3070 1.1375 1.0063 0.9010 0.8143 0.7415 0.6794 0.6257 0.5790
1.25 1.5305 1.1532 0.9449 0.8050 0.7021 0.6223 0.5582 0.5052 0.4607 0.4227 0.3898
Is = 1.3 IB
Iph/IBseq 1.85 1.90 1.95 2.00 2.20 2.40 2.60 2.80 3.00 3.20 3.40 3.60 3.80 4.00
Itrip/IBseq
1.05 2.4177 2.2661 2.1292 2.0051 1.6074 1.3211 1.1071 0.9424 0.8126 0.7084 0.6233 0.5529 0.4939 0.4440
1.10 1.2021 1.1249 1.0555 0.9927 0.7927 0.6498 0.5435 0.4619 0.3979 0.3465 0.3047 0.2701 0.2412 0.2167
1.15 0.7753 0.7242 0.6785 0.6372 0.5066 0.4141 0.3456 0.2933 0.2523 0.2195 0.1929 0.1709 0.1525 0.1370
1.20 0.5378 0.5013 0.4688 0.4396 0.3478 0.2834 0.2360 0.1999 0.1717 0.1493 0.1310 0.1160 0.1035 0.0929
1.25 0.3611 0.3358 0.3134 0.2933 0.2309 0.1874 0.1557 0.1316 0.1129 0.0981 0.0860 0.0761 0.0678 0.0609
Is = 1.4 Ib
Iph/IBseq 1.10 1.15 1.20 1.25 1.30 1.35 1.40 1.45 1.50 1.55 1.60 1.65 1.70 1.75 1.80
Itrip/IBseq
1.05 21.4400 15.8850 12.8490 10.8300 9.3578 8.2251 7.3214 6.5815 5.9634 5.4391 4.9887 4.5976 4.2550 3.9525 3.6837
1.10 9.9827 7.4306 6.0317 5.0988 4.4171 3.8914 3.4710 3.1261 2.8375 2.5922 2.3811 2.1975 2.0364 1.8939
1.15 6.1214 4.5762 3.7270 3.1593 2.7435 2.4222 2.1647 1.9531 1.7757 1.6246 1.4944 1.3810 1.2813
1.20 4.1525 3.1170 2.5464 2.1642 1.8836 1.6664 1.4920 1.3483 1.2278 1.1249 1.0361 0.9587
1.25 2.9310 2.2085 1.8095 1.5416 1.3446 1.1918 1.0689 0.9676 0.8823 0.8095 0.7466
1.30 2.0665 1.5627 1.2839 1.0964 0.9582 0.8508 0.7643 0.6929 0.6327 0.5813
1.35 1.3673 1.0375 0.8546 0.7314 0.6404 0.5696 0.5125 0.4653 0.4254
Is = 1.4 Ib
Iph/IBseq 1.85 1.90 1.95 2.00 2.20 2.40 2.60 2.80 3.00 3.20 3.40 3.60 3.80 4.00
Itrip/IBseq
1.05 3.4434 3.2275 3.0325 2.8557 2.2894 1.8816 1.5768 1.3422 1.1573 1.0089 0.8877 0.7874 0.7034 0.6323
1.10 1.7672 1.6537 1.5516 1.4593 1.1654 0.9552 0.7989 0.6791 0.5849 0.5094 0.4479 0.3970 0.3545 0.3186
1.15 1.1931 1.1145 1.0440 0.9805 0.7796 0.6372 0.5318 0.4513 0.3882 0.3378 0.2968 0.2629 0.2346 0.2107
1.20 0.8906 0.8302 0.7763 0.7279 0.5760 0.4692 0.3907 0.3310 0.2844 0.2472 0.2170 0.1921 0.1714 0.1538
1.25 0.6916 0.6432 0.6002 0.5618 0.4421 0.3589 0.2981 0.2521 0.2163 0.1878 0.1647 0.1457 0.1299 0.1165
1.30 0.5367 0.4977 0.4634 0.4328 0.3386 0.2738 0.2268 0.1914 0.1640 0.1422 0.1246 0.1102 0.0981 0.0880
1.35 0.3913 0.3617 0.3358 0.3129 0.2431 0.1957 0.1617 0.1361 0.1164 0.1009 0.0883 0.0780 0.0694 0.0622
Is = 2 IB
3
Iph/IBseq 1.85 1.90 1.95 2.00 2.20 2.40 2.60 2.80 3.00 3.20 3.40 3.60 3.80 4.00
Itrip/IBseq
1.05 11.1840 10.4830 9.8495 9.2753 7.4358 6.1115 5.1214 4.3594 3.7590 3.2768 2.8832 2.5574 2.2846 2.0537
1.10 6.0114 5.6254 5.2781 4.9642 3.9642 3.2494 2.7177 2.3099 1.9896 1.7328 1.5235 1.3506 1.2059 1.0836
1.15 4.2947 4.0117 3.7581 3.5295 2.8064 2.2936 1.9142 1.6245 1.3975 1.2159 1.0683 0.9464 0.8446 0.7586
1.20 3.4426 3.2091 3.0008 2.8138 2.2265 1.8138 1.5104 1.2795 1.0993 0.9555 0.8388 0.7426 0.6624 0.5946
1.25 2.9368 2.7311 2.5486 2.3855 1.8775 1.5240 1.2659 1.0704 0.9184 0.7974 0.6994 0.6187 0.5515 0.4949
1.30 2.6048 2.4157 2.2489 2.1007 1.6433 1.3288 1.1007 0.9289 0.7958 0.6901 0.6047 0.5346 0.4762 0.4271
1.35 2.3729 2.1935 2.0365 1.8978 1.4745 1.1871 0.9804 0.8257 0.7061 0.6116 0.5354 0.4730 0.4210 0.3774
1.40 2.2046 2.0301 1.8787 1.7459 1.3461 1.0785 0.8878 0.7459 0.6369 0.5509 0.4817 0.4252 0.3782 0.3388
1.50 1.9875 1.8112 1.6620 1.5337 1.1600 0.9190 0.7509 0.6276 0.5337 0.4603 0.4016 0.3538 0.3143 0.2812
1.60 1.8779 1.6825 1.5240 1.3920 1.0256 0.8008 0.6484 0.5386 0.4560 0.3920 0.3411 0.2998 0.2659 0.2376
1.70 1.8713 1.6215 1.4355 1.2893 0.9143 0.7007 0.5610 0.4625 0.3895 0.3335 0.2894 0.2538 0.2246 0.2004
Is = 1.2 IB
Iph/IBseq 1.85 1.90 1.95 2.00 2.20 2.40 2.60 2.80 3.00 3.20 3.40 3.60 3.80 4.00
Itrip/IBseq
1.05 0.1630 0.1511 0.1405 0.1311 0.1020 0.0821 0.0677 0.0569 0.0486 0.0421 0.0368 0.0325 0.0289 0.0259
1.10 0.1398 0.1293 0.1201 0.1119 0.0867 0.0696 0.0573 0.0481 0.0410 0.0354 0.0310 0.0273 0.0243 0.0217
1.15 0.1082 0.0999 0.0926 0.0861 0.0664 0.0531 0.0436 0.0366 0.0312 0.0269 0.0235 0.0207 0.0184 0.0165
3 Is = 1.3 IB
Iph/IBseq 1.10 1.15 1.20 1.25 1.30 1.35 1.40 1.45 1.50 1.55 1.60 1.65 1.70 1.75 1.80
Itrip/IBseq
1.05 4.1639 2.3784 1.6492 1.2509 1.0000 0.8276 0.7021 0.6068 0.5320 0.4719 0.4226 0.3815 0.3467 0.3170 0.2913
1.10 2.9020 1.7875 1.2878 1.0000 0.8123 0.6802 0.5823 0.5068 0.4470 0.3984 0.3583 0.3246 0.2959 0.2713
1.15 2.0959 1.3521 1.0000 0.7901 0.6498 0.5493 0.4737 0.4148 0.3676 0.3291 0.2970 0.2699 0.2468
1.20 1.5014 1.0000 0.7541 0.6039 0.5017 0.4274 0.3708 0.3264 0.2905 0.2610 0.2364 0.2154
1.25 1.0000 0.6820 0.5222 0.4227 0.3541 0.3036 0.2648 0.2341 0.2092 0.1886 0.1713
Is = 1.3 IB
Iph/IBseq 1.85 1.90 1.95 2.00 2.20 2.40 2.60 2.80 3.00 3.20 3.40 3.60 3.80 4.00
Itrip/IBseq
1.05 0.2688 0.2491 0.2317 0.2162 0.1682 0.1354 0.1117 0.0939 0.0802 0.0694 0.0607 0.0535 0.0476 0.0426
1.10 0.2499 0.2311 0.2146 0.2000 0.1550 0.1243 0.1023 0.0859 0.0733 0.0633 0.0554 0.0488 0.0434 0.0389
1.15 0.2268 0.2094 0.1941 0.1805 0.1393 0.1114 0.0915 0.0767 0.0653 0.0564 0.0492 0.0434 0.0386 0.0345
1.20 0.1974 0.1819 0.1682 0.1562 0.1199 0.0955 0.0783 0.0655 0.0557 0.0481 0.0419 0.0369 0.0328 0.0293
1.25 0.1565 0.1438 0.1327 0.1230 0.0938 0.0745 0.0609 0.0508 0.0432 0.0372 0.0324 0.0285 0.0253 0.0226
Is = 1.4 IB
Iph/IBseq 1.10 1.15 1.20 1.25 1.30 1.35 1.40 1.45 1.50 1.55 1.60 1.65 1.70 1.75 1.80
Itrip/IBseq
1.05 5.9304 3.3874 2.3488 1.7816 1.4243 1.1788 1.0000 0.8642 0.7577 0.6721 0.6019 0.5434 0.4938 0.4515 0.4148
1.10 4.2662 2.6278 1.8931 1.4701 1.1942 1.0000 0.8560 0.7451 0.6571 0.5857 0.5267 0.4771 0.4350 0.3988
1.15 3.2252 2.0806 1.5388 1.2158 1.0000 0.8453 0.7289 0.6383 0.5657 0.5064 0.4570 0.4154 0.3797
1.20 2.4862 1.6559 1.2488 1.0000 0.8307 0.7077 0.6141 0.5405 0.4811 0.4323 0.3914 0.3567
1.25 1.9151 1.3061 1.0000 0.8095 0.6780 0.5814 0.5072 0.4484 0.4007 0.3612 0.3280
1.30 1.4393 1.0000 0.7750 0.6330 0.5339 0.4603 0.4035 0.3581 0.3211 0.2903
1.35 1.0000 0.7053 0.5521 0.4544 0.3855 0.3340 0.2940 0.2618 0.2355
Is = 1.4 IB
Iph/IBseq 1.85 1.90 1.95 2.00 2.20 2.40 2.60 2.80 3.00 3.20 3.40 3.60 3.80 4.00
Itrip/IBseq
1.05 0.3829 0.3548 0.3300 0.3079 0.2396 0.1928 0.1590 0.1337 0.1142 0.0988 0.0864 0.0762 0.0678 0.0607
1.10 0.3673 0.3398 0.3155 0.2940 0.2278 0.1828 0.1505 0.1263 0.1078 0.0931 0.0814 0.0718 0.0638 0.0571
1.15 0.3490 0.3222 0.2986 0.2778 0.2143 0.1714 0.1408 0.1180 0.1005 0.0868 0.0758 0.0668 0.0593 0.0531
1.20 0.3269 0.3011 0.2786 0.2587 0.1985 0.1582 0.1296 0.1085 0.0923 0.0796 0.0694 0.0611 0.0543 0.0486
1.25 0.2997 0.2753 0.2541 0.2355 0.1796 0.1426 0.1165 0.0973 0.0827 0.0712 0.0621 0.0546 0.0485 0.0433
1.30 0.2643 0.2420 0.2228 0.2060 0.1561 0.1235 0.1006 0.0838 0.0711 0.0612 0.0533 0.0468 0.0415 0.0371
1.35 0.2135 0.1948 0.1788 0.1649 0.1240 0.0976 0.0793 0.0659 0.0558 0.0480 0.0417 0.0367 0.0325 0.0290
Is = 2 IB
3
Iph/IBseq 1.85 1.90 1.95 2.00 2.20 2.40 2.60 2.80 3.00 3.20 3.40 3.60 3.80
2
4.00
Itrip/IBseq leq
---------
t lB
1.05 1.2436 1.1525 1.0718 1.0000 0.7783 0.6262 0.5165 0.4343 0.3709 0.3209 0.2806--- =0.2476 0.2202 - 0.1972
l N ------------------------------
2
1.10 1.2495 1.1559 1.0733 1.0000 0.7750 0.6217 0.5118 0.4297 0.3666 0.3168 0.2768T 0.2441 leq
---------0.2170 Es 0.1943
1.15 1.2562 1.1597 1.0750 1.0000 0.7713 0.6169 0.5066 0.4247 0.3618 0.3124
0.2727 0.2404l B 0.2136 0.1911
1.20 1.2638 1.1640 1.0768 1.0000 0.7673 0.6115 0.5010 0.4192 0.3567 0.3076 0.2683 0.2363 0.2099 0.1877
2
1.25 1.2725 1.1690 1.0790 1.0000 0.7628 0.6057 0.4949 0.4133 0.3511 0.3025 0.2636 0.2320 leq - 1
--------0.2059 0.1841
1.30 1.2826 1.1747 1.0814 1.0000 0.7578 0.5992 0.4882 0.4069 0.3451 0.2969 0.2585 t 0.2274 l B0.2017 0.1802
--- = l N ------------------------------
2
-
1.35 1.2945 1.1813 1.0842 1.0000 0.7522 0.5920 0.4808 0.3998 0.3386 0.2910 0.2531T 0.2224 leq0.1971
-------- 0.1760
- Es
1.40 1.3085 1.1891 1.0874 1.0000 0.7459 0.5841 0.4728 0.3921 0.3315 0.2844 0.2471 0.2170 l B 0.1922 0.1715
1.50 1.3463 1.2094 1.0958 1.0000 0.7306 0.5652 0.4539 0.3744 0.3152 0.2697 0.2337 0.2048 0.1811 0.1614
1.60 1.4070 1.2406 1.1082 1.0000 0.7102 0.5410 0.4303 0.3527 0.2955 0.2520 0.2178 0.1904 0.1681 0.1496
1.70 1.5237 1.2953 1.1286 1.0000 0.6816 0.5089 0.4000 0.3253 0.2711 0.2302 0.1983 0.1730 0.1524 0.1355
Operation Curve
The protection issues a trip command when the heat rise E (calculated by measuring
an equivalent current Ieq) is greater than the heat rise set point Es.
I = I B Es
101
DE50808
100
10-1
10-2
10-3
0 5 10
MT10420
0,63
0,36
0 0
T1 t T2 t
Heat rise time constant Cooling time constant
For self-ventilated rotating machines, cooling is more effective when the machine is
running than when it is stopped. Running and stopping of the equipment are
calculated based on the value of the current:
b running if I > 0.1 IB
b stopped if I < 0.1 IB
b a second group of parameters (time constants and set points) is used for
thermal withstand with locked rotors. This second set of parameters applies
when the current is greater than an adjustable set point Is.
Because the function has two operating modes, a time constant is estimated for each
mode.
Block Start
The thermal overload protection can block the closing of the motor control device
until the heat rise drops back down below a value that allows restarting. This value
addresses the heat rise produced by motor startup.
The block function is grouped together with the starts per hour protection function
and the indication BLOCK START informs the user.
Blocking Tripping
Tripping of the thermal overload protection can be blocked by the logic input "Block
thermal overload" when required by the process.
The protection function comprises two groups of settings, and each group is suitable
for equipment protection in one of the two operating modes.
Switching from one group of thermal settings to the other is done without losing the
heat rise information. It is controlled:
b either via a logic input, assigned to the "switching of thermal settings" function
b or when the phase current reaches an adjustable Is set point (to be used for
switching of thermal settings of a motor with locked rotor).
The base current of the equipment, used to calculate heat rise, also depends on the
operating mode:
b for logic input switching in mode 2, the base current IB-mode 2, a specific
thermal overload protection setting, is used to calculate the heat rise in the
equipment
b in all other cases, the base current IB, defined as a general Sepam
parameter, is used to calculate the heat rise in the equipment.
User Information
The following information is available for the user:
b heat rise
b learned cooling time constant T2
b time before restart enabled (in case of blocking starting)
b time before tripping (with constant current).
Block Diagram
DE51636
block closing
Block Start
& indication
Characteristics
Settings Inputs
Measurement Origin Designation Syntax Equations Logipam
Setting range Ia, Ib, Ic / I'a, I'b, I'c Protection reset P49RMS_1_101 b b
Considering the Negative Sequence Component K Protection blocking P49RMS_1_113 b b
Setting range 0 - 2.25 - 4.59 Outputs
Considering Ambient Temperature Designation Syntax Equations Logipam Matrix
Setting range Yes / no Delayed output P49RMS_1_3 b b b
Using the Learned Cooling Time Constant T2 Alarm P49RMS_1_10 b b b
Setting range Yes / no Block closing P49RMS_1_11 b b b
Maximum equipment temperature Tmax (according to Protection blocked P49RMS_1_16 b b
insulation class) Hot state P49RMS_1_18 b b
Setting range 140 F to 392 F or 60 C to 200 C Block thermal overload P49RMS_1_32 b b
Resolution 1F or 1C
Thermal Mode 1
Alarm Set Point Es1
Setting range
Accuracy (1)
0% to 300%
2%
3
Resolution 1%
Tripping Set Point Es2
Setting range 0% to 300%
Accuracy (1) 2%
Resolution 1%
Initial Heat Rise Set Point Es0
Setting range 0% to 100%
Accuracy (1) 2%
Resolution 1%
Heat Rise Time Constant T1
Setting range 1 min. to 600 min.
Resolution 1 min.
Cooling Time Constant T2
Setting range 5 min. to 600 min.
Resolution 1 min.
Thermal Mode 2
Using Thermal Mode 2
Setting range Yes / no
Alarm Set Point Es1
Setting range 0% to 300%
Accuracy (1) 2%
Resolution 1%
Tripping Set Point Es2
Setting range 0% to 300%
Accuracy (1) 2%
Resolution 1%
Initial Heat Rise Set Point Es0
Setting range 0% to 100%
Accuracy (1) 2%
Resolution 1%
Heat Rise Time Constant T1
Setting range 1 min. to 600 min.
Resolution 1 min.
Cooling Time Constant T2
Setting range 5 min. to 600 min.
Resolution 1 min.
Switching Set Point for Thermal Mode 2
Setting range 25% to 800% of IB
Accuracy (1) 5%
Resolution 1%
Base Current IB - Mode 2
Setting range 0.2 to 2.6 IN or IN
Accuracy (1) 5%
Resolution 1A
Characteristic Times (1)
Operation time accuracy 2% or 1 s
(1) Under reference conditions (IEC 60255-8).
Example 1: Motor For an overload of 2 IB, the value t/T1 = 0.0339 (2).
The following data are available: In order for Sepam to trip at point 1 (t = 70 s), T1 is equal to 2065 sec 34 min.
b time constants for on operation T1 and off
operation T2: With a setting of T1 = 34 min., the tripping time is obtained based on a cold state
v T1 = 25 min. (point 2). Here, it is equal to t/T1 = 0.3216 t = 665 sec, that is,. 11 minutes, which
v T2 = 70 min. is compatible with the motor thermal withstand when it is cold.
b maximum steady state current:
v Imax/IB = 1.05. The negative sequence factor K is calculated using the equation defined on
page 109.
Setting the Tripping Set Point Es2
Es2 = (Imax/IB)2 = 110%
The parameters of the second thermal overload relay do not need to be set. They
Nota : If the motor draws a current of 1.05 IB continuously, the are not considered by default.
heat rise calculated by the thermal overload protection will
reach 110%.
Example 3: Motor
Setting Alarm Set Point Es1 The following data are available:
Es1 = 90% (I/IB = 0.95). b motor thermal withstand in the form of hot and cold curves (see solid line
Knegative: 4.5 (usual value) curves in Figure 2)
The manufacturer's hot/cold curves (1) may be used to This tripping time is too long since the limit for this overload current is 400 sec
determine the heating time constant T1. (point 2).
The method consists of placing the Sepam hot/cold If the time constant T1 is lowered, the thermal overload protection will trip earlier,
curves below those of the motor. below point 2.
Figure 1. Motor thermal withstand and thermal The risk that motor starting when hot will not be possible also exists in this case (see
overload tripping curves. Figure 2 in which a lower Sepam hot curve would intersect the starting curve with
VLL = 0.9 VLL).
MT10860
motor cold curve The Es0 parameter is a setting that is used to solve these differences by lowering
the Sepam cold curve without moving the hot curve. In this example, the thermal
Sepam cold curve
overload protection should trip after 400 sec starting from the cold state.
time before tripping/s
(1) When the machine manufacturer provides both a time constant T1 and the machine hot/cold
curves, the use of the curves is recommended since they are more accurate.
(2) It is possible to use the charts containing the numerical values of the Sepam hot curve or
the equation of the curve which is given on page 108.
In numerical values, the following is obtained: Using the Additional Setting Group
400 s
----------------------- When a motor rotor is locked or turning very slowly, its thermal behavior differs from
24 60 s
Es0 = 4 e 4 ( 1.2 ) = 0.3035 ( 31 % ) one with a rated load. In such conditions, the motor is damaged by overheating of
By setting Es0 = 31%, point 2 is moved downward to the rotor or stator. For high power motors, rotor overheating is usually a limiting factor.
obtain a shorter tripping time that is compatible with the
motor thermal withstand when cold (see Figure 3). The thermal overload parameters selected to operate with a low overload are no
longer valid. In order to protect the motor in this case, "excessive starting time"
Nota : A setting Es0 = 100% means that the hot and cold
curves are the same. protection may be used.
However, motor manufacturers provide the thermal withstand curves when the rotor
Figure 2. Hot/cold curves incompatible with the is locked, for different voltages at the time of starting.
motor thermal withstand.
MT10863
513 2
motor cold curve
3
time before tripping/s
400 2
motor hot curve
times / s
100 1
1 Sepam hot curve
3
starting at VLLn 2
starting at 0.9 VLLn
1.05 2 I/IB
4 5 6
1.1 2 Is I/IB
Figure 3. Hot/cold curves compatible with the 1 : thermal withstand, motor running
motor thermal withstand via the setting of an initial 2 : thermal withstand, motor stopped
heat rise Es0.
3 : Sepam tripping curve
adjusted Sepam
cold curve 5 : starting at 80% VLL
400
2
motor hot curve In order to consider these curves, a second thermal overload relay can be used.
The time constant in this case is theoretically shorter. It should, however, be
100 determined in the same way as that of the first relay.
1 Sepam hot curve
The thermal overload protection switches between the first and second relay if the
equivalent current Ieq exceeds the Is value (set point current).
starting at VLLn
starting at 0.9 VLLn
Example 4. Transformer with Two Ventilation Modes
1.1 2 I/IB The following data are available:
The rated current of a transformer with two ventilation modes is:
b IB = 200 A without forced ventilation (ONAN mode), the main operating mode
of the transformer
b IB = 240 A with forced ventilation (ONAF mode), a temporary operating mode,
to have 20% more power available
Setting the base current for ventilation operating mode 1: IB = 200 A (to be set in the
Sepam general parameters).
Setting the base current for ventilation operating mode 2: IB2 = 240 A (to be set
among the specific thermal overload protection settings).
Settings related to each ventilation operating mode (Es set points, time constants,
etc.) are determined according to transformer characteristics provided by the
manufacturer.
3 115
120
3.0040 2.0369
2.3792
1.6025
1.7918
1.3318
1.4610
1.1409
1.2381
0.9970
1.0742
0.8837
0.9474
0.7918
0.8457
0.7156
0.7621
0.6514
0.6921
0.5964
0.6325
0.5489
0.5812
0.5074
0.5365
0.4708
0.4973
0.4384
0.4626
125 2.9037 2.0254 1.6094 1.3457 1.1580 1.0154 0.9027 0.8109 0.7346 0.6700 0.6146 0.5666 0.5245 0.4874
130 2.3308 1.7838 1.4663 1.2493 1.0885 0.9632 0.8622 0.7789 0.7089 0.6491 0.5975 0.5525 0.5129
135 2.7726 1.9951 1.6035 1.3499 1.1672 1.0275 0.9163 0.8253 0.7494 0.6849 0.6295 0.5813 0.5390
140 2.2634 1.7626 1.4618 1.2528 1.0962 0.9734 0.8740 0.7916 0.7220 0.6625 0.6109 0.5658
145 2.6311 1.9518 1.5877 1.3463 1.1701 1.0341 0.9252 0.8356 0.7606 0.6966 0.6414 0.5934
150 3.2189 2.1855 1.7319 1.4495 1.2498 1.0986 0.9791 0.8817 0.8007 0.7320 0.6729 0.6217
155 2.4908 1.9003 1.5645 1.3364 1.1676 1.0361 0.9301 0.8424 0.7686 0.7055 0.6508
160 2.9327 2.1030 1.6946 1.4313 1.2417 1.0965 0.9808 0.8860 0.8066 0.7391 0.6809
165 2.3576 1.8441 1.5361 1.3218 1.1609 1.0343 0.9316 0.8461 0.7739 0.7118
170 2.6999 2.0200 1.6532 1.4088 1.2296 1.0908 0.9793 0.8873 0.8099 0.7438
175 3.2244 2.2336 1.7858 1.5041 1.3035 1.1507 1.0294 0.9302 0.8473 0.7768
180 2.5055 1.9388 1.6094 1.3832 1.2144 1.0822 0.9751 0.8861 0.8109
185 2.8802 2.1195 1.7272 1.4698 1.2825 1.1379 1.0220 0.9265 0.8463
190 3.4864 2.3401 1.8608 1.5647 1.3555 1.1970 1.0713 0.9687 0.8829
195 2.6237 2.0149 1.6695 1.4343 1.2597 1.1231 1.0126 0.9209
200 3.0210 2.1972 1.7866 1.5198 1.3266 1.1778 1.0586 0.9605
3 115
120
0.0512
0.0535
0.0471
0.0492
0.0388
0.0405
0.0325
0.0339
0.0276
0.0288
0.0237
0.0248
0.0207
0.0216
0.0181
0.0189
0.0160
0.0167
0.0143
0.0149
0.0128
0.0134
0.0116
0.0121
0.0074
0.0077
0.0051
0.0053
0.0038
0.0039
0.0029
0.0030
125 0.0558 0.0513 0.0422 0.0353 0.0300 0.0258 0.0225 0.0197 0.0175 0.0156 0.0139 0.0126 0.0080 0.0056 0.0041 0.0031
130 0.0581 0.0534 0.0439 0.0368 0.0313 0.0269 0.0234 0.0205 0.0182 0.0162 0.0145 0.0131 0.0084 0.0058 0.0043 0.0033
135 0.0604 0.0555 0.0457 0.0382 0.0325 0.0279 0.0243 0.0213 0.0189 0.0168 0.0151 0.0136 0.0087 0.0060 0.0044 0.0034
140 0.0627 0.0576 0.0474 0.0397 0.0337 0.0290 0.0252 0.0221 0.0196 0.0174 0.0156 0.0141 0.0090 0.0062 0.0046 0.0035
145 0.0650 0.0598 0.0491 0.0411 0.0349 0.0300 0.0261 0.0229 0.0203 0.0181 0.0162 0.0146 0.0093 0.0065 0.0047 0.0036
150 0.0673 0.0619 0.0509 0.0426 0.0361 0.0311 0.0270 0.0237 0.0210 0.0187 0.0168 0.0151 0.0096 0.0067 0.0049 0.0038
155 0.0696 0.0640 0.0526 0.0440 0.0374 0.0321 0.0279 0.0245 0.0217 0.0193 0.0173 0.0156 0.0100 0.0069 0.0051 0.0039
160 0.0720 0.0661 0.0543 0.0455 0.0386 0.0332 0.0289 0.0253 0.0224 0.0200 0.0179 0.0161 0.0103 0.0071 0.0052 0.0040
165 0.0743 0.0683 0.0561 0.0469 0.0398 0.0343 0.0298 0.0261 0.0231 0.0206 0.0185 0.0166 0.0106 0.0074 0.0054 0.0041
170 0.0766 0.0704 0.0578 0.0484 0.0411 0.0353 0.0307 0.0269 0.0238 0.0212 0.0190 0.0171 0.0109 0.0076 0.0056 0.0043
175 0.0790 0.0726 0.0596 0.0498 0.0423 0.0364 0.0316 0.0277 0.0245 0.0218 0.0196 0.0177 0.0113 0.0078 0.0057 0.0044
180 0.0813 0.0747 0.0613 0.0513 0.0435 0.0374 0.0325 0.0285 0.0252 0.0225 0.0201 0.0182 0.0116 0.0080 0.0059 0.0045
185 0.0837 0.0769 0.0631 0.0528 0.0448 0.0385 0.0334 0.0293 0.0259 0.0231 0.0207 0.0187 0.0119 0.0083 0.0061 0.0046
190 0.0861 0.0790 0.0649 0.0542 0.0460 0.0395 0.0344 0.0301 0.0266 0.0237 0.0213 0.0192 0.0122 0.0085 0.0062 0.0048
195 0.0884 0.0812 0.0666 0.0557 0.0473 0.0406 0.0353 0.0309 0.0274 0.0244 0.0218 0.0197 0.0126 0.0087 0.0064 0.0049
200 0.0908 0.0834 0.0684 0.0572 0.0485 0.0417 0.0362 0.0317 0.0281 0.0250 0.0224 0.0202 0.0129 0.0089 0.0066 0.0050
Hot Curves
I/IB 1.00 1.05 1.10 1.15 1.20 1.25 1.30 1.35 1.40 1.45 1.50 1.55 1.60 1.65 1.70 1.75 1.80
Es (%)
105 0.6690 0.2719 0.1685 0.1206 0.0931 0.0752 0.0627 0.0535 0.0464 0.0408 0.0363 0.0326 0.0295 0.0268 0.0245 0.0226
110 3.7136 0.6466 0.3712 0.2578 0.1957 0.1566 0.1296 0.1100 0.0951 0.0834 0.0740 0.0662 0.0598 0.0544 0.0497 0.0457
115 1.2528 0.6257 0.4169 0.3102 0.2451 0.2013 0.1699 0.1462 0.1278 0.1131 0.1011 0.0911 0.0827 0.0755 0.0693
120 3.0445 0.9680 0.6061 0.4394 0.3423 0.2786 0.2336 0.2002 0.1744 0.1539 0.1372 0.1234 0.1118 0.1020 0.0935
125 1.4925 0.8398 0.5878 0.4499 0.3623 0.3017 0.2572 0.2231 0.1963 0.1747 0.1568 0.1419 0.1292 0.1183
130 2.6626 1.1451 0.7621 0.5705 0.4537 0.3747 0.3176 0.2744 0.2407 0.2136 0.1914 0.1728 0.1572 0.1438
135 1.5870 0.9734 0.7077 0.5543 0.4535 0.3819 0.3285 0.2871 0.2541 0.2271 0.2048 0.1860 0.1699
140 2.3979 1.2417 0.8668 0.6662 0.5390 0.4507 0.3857 0.3358 0.2963 0.2643 0.2378 0.2156 0.1967
145 1.6094 1.0561 0.7921 0.6325 0.5245 0.4463 0.3869 0.3403 0.3028 0.2719 0.2461 0.2243
150 2.1972 1.2897 0.9362 0.7357 0.6042 0.5108 0.4408 0.3864 0.3429 0.3073 0.2776 0.2526
155 3.8067 1.5950 1.1047 0.8508 0.6909 0.5798 0.4978 0.4347 0.3846 0.3439 0.3102 0.2817
160 2.0369 1.3074 0.9808 0.7857 0.6539 0.5583 0.4855 0.4282 0.3819 0.3438 0.3118
165 2.8478 1.5620 1.1304 0.8905 0.7340 0.6226 0.5390 0.4738 0.4215 0.3786 0.3427
170
175
1.9042
2.4288
1.3063
1.5198
1.0076
1.1403
0.8210
0.9163
0.6914
0.7652
0.5955
0.6554
0.5215
0.5717
0.4626
0.5055
0.4146
0.4520
0.3747
0.4077
3
180 3.5988 1.7918 1.2933 1.0217 0.8449 0.7191 0.6244 0.5504 0.4908 0.4418
185 2.1665 1.4739 1.1394 0.9316 0.7872 0.6802 0.5974 0.5312 0.4772
190 2.7726 1.6946 1.2730 1.0264 0.8602 0.7392 0.6466 0.5733 0.5138
195 4.5643 1.9782 1.4271 1.1312 0.9390 0.8019 0.6985 0.6173 0.5518
200 2.3755 1.6094 1.2483 1.0245 0.8688 0.7531 0.6633 0.5914
I/IB 1.85 1.90 1.95 2.00 2.20 2.40 2.60 2.80 3.00 3.20 3.40 3.60 3.80 4.00 4.20 4.40 4.60
Es (%)
105 0.0209 0.0193 0.0180 0.0168 0.0131 0.0106 0.0087 0.0073 0.0063 0.0054 0.0047 0.0042 0.0037 0.0033 0.0030 0.0027 0.0025
110 0.0422 0.0391 0.0363 0.0339 0.0264 0.0212 0.0175 0.0147 0.0126 0.0109 0.0095 0.0084 0.0075 0.0067 0.0060 0.0055 0.0050
115 0.0639 0.0592 0.0550 0.0513 0.0398 0.0320 0.0264 0.0222 0.0189 0.0164 0.0143 0.0126 0.0112 0.0101 0.0091 0.0082 0.0075
120 0.0862 0.0797 0.0740 0.0690 0.0535 0.0429 0.0353 0.0297 0.0253 0.0219 0.0191 0.0169 0.0150 0.0134 0.0121 0.0110 0.0100
125 0.1089 0.1007 0.0934 0.0870 0.0673 0.0540 0.0444 0.0372 0.0317 0.0274 0.0240 0.0211 0.0188 0.0168 0.0151 0.0137 0.0125
130 0.1322 0.1221 0.1132 0.1054 0.0813 0.0651 0.0535 0.0449 0.0382 0.0330 0.0288 0.0254 0.0226 0.0202 0.0182 0.0165 0.0150
135 0.1560 0.1440 0.1334 0.1241 0.0956 0.0764 0.0627 0.0525 0.0447 0.0386 0.0337 0.0297 0.0264 0.0236 0.0213 0.0192 0.0175
140 0.1805 0.1664 0.1540 0.1431 0.1100 0.0878 0.0720 0.0603 0.0513 0.0443 0.0386 0.0340 0.0302 0.0270 0.0243 0.0220 0.0200
145 0.2055 0.1892 0.1750 0.1625 0.1246 0.0993 0.0813 0.0681 0.0579 0.0499 0.0435 0.0384 0.0341 0.0305 0.0274 0.0248 0.0226
150 0.2312 0.2127 0.1965 0.1823 0.1395 0.1110 0.0908 0.0759 0.0645 0.0556 0.0485 0.0427 0.0379 0.0339 0.0305 0.0276 0.0251
155 0.2575 0.2366 0.2185 0.2025 0.1546 0.1228 0.1004 0.0838 0.0712 0.0614 0.0535 0.0471 0.0418 0.0374 0.0336 0.0304 0.0277
160 0.2846 0.2612 0.2409 0.2231 0.1699 0.1347 0.1100 0.0918 0.0780 0.0671 0.0585 0.0515 0.0457 0.0408 0.0367 0.0332 0.0302
165 0.3124 0.2864 0.2639 0.2442 0.1855 0.1468 0.1197 0.0999 0.0847 0.0729 0.0635 0.0559 0.0496 0.0443 0.0398 0.0360 0.0328
170 0.3410 0.3122 0.2874 0.2657 0.2012 0.1591 0.1296 0.1080 0.0916 0.0788 0.0686 0.0603 0.0535 0.0478 0.0430 0.0389 0.0353
175 0.3705 0.3388 0.3115 0.2877 0.2173 0.1715 0.1395 0.1161 0.0984 0.0847 0.0737 0.0648 0.0574 0.0513 0.0461 0.0417 0.0379
180 0.4008 0.3660 0.3361 0.3102 0.2336 0.1840 0.1495 0.1244 0.1054 0.0906 0.0788 0.0692 0.0614 0.0548 0.0493 0.0446 0.0405
185 0.4321 0.3940 0.3614 0.3331 0.2502 0.1967 0.1597 0.1327 0.1123 0.0965 0.0839 0.0737 0.0653 0.0583 0.0524 0.0474 0.0431
190 0.4644 0.4229 0.3873 0.3567 0.2671 0.2096 0.1699 0.1411 0.1193 0.1025 0.0891 0.0782 0.0693 0.0619 0.0556 0.0503 0.0457
195 0.4978 0.4525 0.4140 0.3808 0.2842 0.2226 0.1802 0.1495 0.1264 0.1085 0.0943 0.0828 0.0733 0.0654 0.0588 0.0531 0.0483
200 0.5324 0.4831 0.4413 0.4055 0.3017 0.2358 0.1907 0.1581 0.1335 0.1145 0.0995 0.0873 0.0773 0.0690 0.0620 0.0560 0.0509
Hot Curves
I/IB 4.80 5.00 5.50 6.00 6.50 7.00 7.50 8.00 8.50 9.00 9.50 10.00 12.50 15.00 17.50 20.00
Es (%)
105 0.0023 0.0021 0.0017 0.0014 0.0012 0.0010 0.0009 0.0008 0.0007 0.0006 0.0006 0.0005 0.0003 0.0002 0.0002 0.0001
110 0.0045 0.0042 0.0034 0.0029 0.0024 0.0021 0.0018 0.0016 0.0014 0.0013 0.0011 0.0010 0.0006 0.0004 0.0003 0.0003
115 0.0068 0.0063 0.0051 0.0043 0.0036 0.0031 0.0027 0.0024 0.0021 0.0019 0.0017 0.0015 0.0010 0.0007 0.0005 0.0004
120 0.0091 0.0084 0.0069 0.0057 0.0049 0.0042 0.0036 0.0032 0.0028 0.0025 0.0022 0.0020 0.0013 0.0009 0.0007 0.0005
125 0.0114 0.0105 0.0086 0.0072 0.0061 0.0052 0.0045 0.0040 0.0035 0.0031 0.0028 0.0025 0.0016 0.0011 0.0008 0.0006
130 0.0137 0.0126 0.0103 0.0086 0.0073 0.0063 0.0054 0.0048 0.0042 0.0038 0.0034 0.0030 0.0019 0.0013 0.0010 0.0008
135 0.0160 0.0147 0.0120 0.0101 0.0085 0.0073 0.0064 0.0056 0.0049 0.0044 0.0039 0.0035 0.0023 0.0016 0.0011 0.0009
140 0.0183 0.0168 0.0138 0.0115 0.0097 0.0084 0.0073 0.0064 0.0056 0.0050 0.0045 0.0040 0.0026 0.0018 0.0013 0.0010
145 0.0206 0.0189 0.0155 0.0129 0.0110 0.0094 0.0082 0.0072 0.0063 0.0056 0.0051 0.0046 0.0029 0.0020 0.0015 0.0011
150 0.0229 0.0211 0.0172 0.0144 0.0122 0.0105 0.0091 0.0080 0.0070 0.0063 0.0056 0.0051 0.0032 0.0022 0.0016 0.0013
155 0.0253 0.0232 0.0190 0.0158 0.0134 0.0115 0.0100 0.0088 0.0077 0.0069 0.0062 0.0056 0.0035 0.0025 0.0018 0.0014
160 0.0276 0.0253 0.0207 0.0173 0.0147 0.0126 0.0109 0.0096 0.0085 0.0075 0.0067 0.0061 0.0039 0.0027 0.0020 0.0015
165 0.0299 0.0275 0.0225 0.0187 0.0159 0.0136 0.0118 0.0104 0.0092 0.0082 0.0073 0.0066 0.0042 0.0029 0.0021 0.0016
3 170
175
0.0323
0.0346
0.0296
0.0317
0.0242
0.0260
0.0202
0.0217
0.0171
0.0183
0.0147
0.0157
0.0128
0.0137
0.0112
0.0120
0.0099
0.0106
0.0088
0.0094
0.0079
0.0084
0.0071
0.0076
0.0045
0.0048
0.0031
0.0034
0.0023
0.0025
0.0018
0.0019
180 0.0370 0.0339 0.0277 0.0231 0.0196 0.0168 0.0146 0.0128 0.0113 0.0101 0.0090 0.0081 0.0052 0.0036 0.0026 0.0020
185 0.0393 0.0361 0.0295 0.0246 0.0208 0.0179 0.0155 0.0136 0.0120 0.0107 0.0096 0.0086 0.0055 0.0038 0.0028 0.0021
190 0.0417 0.0382 0.0313 0.0261 0.0221 0.0189 0.0164 0.0144 0.0127 0.0113 0.0101 0.0091 0.0058 0.0040 0.0030 0.0023
195 0.0441 0.0404 0.0330 0.0275 0.0233 0.0200 0.0173 0.0152 0.0134 0.0119 0.0107 0.0096 0.0061 0.0043 0.0031 0.0024
200 0.0464 0.0426 0.0348 0.0290 0.0245 0.0211 0.0183 0.0160 0.0141 0.0126 0.0113 0.0102 0.0065 0.0045 0.0033 0.0025
Automatic activation of this protection function requires the use of the circuit breaker
control function in the control logic. A specific input can also be used to activate the
protection by logic equation or by Logipam. That option is useful for adding special
cases of activation (e.g. tripping by an external protection unit).
Block Diagram
DE51550
considering
considering
Characteristics
Settings
Is Set Point
Setting range 0.2 IN to 2 IN
Accuracy (1) 5%
Resolution 0.1 A
Drop out/pick up ratio 87.5% 2%
Time Delay T
Setting range 50 ms to 3 s
Accuracy (1) 2% or -10 ms to +15 ms
Resolution 10 ms or 1 digit
Considering Circuit Breaker Position
Setting range With / without
Characteristic Times
Overshoot time < 35 ms at 2 Is
Inputs
Designation Syntax Equations Logipam
Protection reset P50BF_1_101 b b
Start 50BF P50BF_1_107 b b
Protection blocking P50BF_1_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P50BF_1_1 b b
Delayed output P50BF_1_3 b b b
Protection blocked P50BF_1_16 b b
(1) Under reference conditions (IEC 60255-6).
Example
Below is an example for determining the time-delay setting of the breaker failure
function. The following parameters are for the illustration:
b overcurrent protection setting: T = inst
b circuit breaker operating time: 60 ms
b auxiliary relay operating time to open the upstream breaker(s): 10 ms.
DE52249
The breaker failure function time delay is the sum of the following times:
b Sepam O1 output relay pick-up time = 10 ms
b circuit breaker opening time = 60 ms
b Breaker failure function overshoot time = 35 ms.
Characteristics
DE50834
Settings
Current Set Point
Setting range 0.5 to 4 IN
Accuracy (1) 5% or 0.02 IN
Resolution 1A
Drop out/pick up ratio 95.5% or 0.015 IN
Voltage Set Point
Setting range 10% to 100% of VLL
Accuracy (1) 2% or 0.005 VLLp
Resolution 1%
Drop out/pick up ratio 103%
Advanced Settings
Use of Breaker Position
Setting range Used / not used
T1 Time
Setting range 0 to 10 s
Accuracy (1) 2% or from -10 ms to +25 ms
Resolution 10 ms or 1 digit
T2 Time
Setting range 0 to 10 s
Example: Generator shutdown and inadvertent starting. Accuracy (1) 2% or from -10 ms to +25 ms
Resolution 10 ms or 1 digit
Characteristic times (1)
Operation time < 40 ms at 2 Is (typically 30 ms)
Inputs
Designation Syntax Equations Logipam
Protection reset P50/27_1_101 b b
Protection blocking P50/27_1_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Tripping output P50/27_1_3 b b b
Protection blocked P50/27_1_16 b b
Protection ready P50/27_1_35 b b
(1) Under reference conditions (IEC 60255-6).
Example
Synchronous generator data
b S = 3.15 MVA
b VLLN1 = 6.3 kV
b Xd = 233%
b X'd = 21%
b X''d = 15%
b the generator is connected to a network with a Psc = 10 MVA
b the maximum admissible duration of a voltage sag is 2.5 seconds.
To set the protection function, it is necessary to calculate the rated generator
impedance:
b IB = S/(3VLLN1) = 289 A
b ZN = VLLN1/ (3IB) = 12.59 .
The network impedance is:
Zpsc = (VLLN1)2/Psc = 3.97 .
Tripping Curve
Definite time (DT)
Timer Hold
Definite time
3
Standard inverse time (SIT) Definite time
Very inverse time (VIT or LTI) Definite time
Extremely inverse time (EIT) Definite time
Ultra inverse time (UIT) Definite time
RI curve Definite time
IEC inverse time SIT / A Definite time or IDMT
IEC very inverse time VIT or LTI / B Definite time or IDMT
IEC extremely inverse time EIT / C Definite time or IDMT
IEEE moderately inverse (IEC / D) Definite time or IDMT
IEEE very inverse (IEC / E) Definite time or IDMT
IEEE extremely inverse (IEC / F) Definite time or IDMT
IAC inverse Definite time or IDMT
IAC very inverse Definite time or IDMT
IAC extremely inverse Definite time or IDMT
Customized Definite time
Block Diagram
pick-up signal and to
zero selective interlocking
DE50782
Characteristics
Settings
Measurement Origin
Setting range Main channels (I) / Additional channels (I)
Tripping Curve
Setting range See previous page
Is Set Point
Setting range Definite time 0.05 IN Is 24 IN expressed in
amperes
IDMT 0.05 IN Is 2.4 IN expressed in
amperes
Accuracy (1) 5% or 0.01 IN
Resolution 1 A or 1 digit
Drop out/pick up ratio 93.5% 5% or > (1 - 0.015 IN/Is) x 100%
Time Delay T (Operation Time at 10 Is)
Setting range Definite time Inst, 50 ms T 300 s
3 Accuracy (1)
IDMT
Definite time
IDMT
100 ms T 12.5 s or TMS (2)
2% or from 10 ms to +25 ms
Class 5 or from 10 ms to +25 ms
Resolution 10 ms or 1 digit
Advanced Settings
Confirmation
Setting range By undervoltage (unit 1)
By negative sequence overvoltage (unit 1)
None, no confirmation
Timer Hold T1
Setting range Definite time 0; 0.05 to 300 s
IDMT (3) 0.5 to 20 s
Resolution 10 ms or 1 digit
Characteristic Times
Operation time pick-up < 35 ms at 2 Is (typically 25 ms)
Inst. < 50 ms at 2 Is (confirmed instantaneous) (typically 35 ms)
Overshoot time < 50 ms at 2 Is
Reset time < 50 ms at 2 Is (for T1 = 0)
Inputs
Designation Syntax Equations Logipam
Protection reset P50/51_x_101 b b
Protection blocking P50/51_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P50/51_x_1 b b
Delayed output P50/51_x_3 b b b
Drop out P50/51_x_4 b b
Phase "a" fault P50/51_x_7 b b
Phase "b" fault P50/51_x_8 b b
Phase "c" fault P50/51_x_9 b b
Protection blocked P50/51_x_16 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
(2) Setting ranges in TMS (Time Multiplier Setting) mode
b Inverse (SIT) and IEC SIT/A: 0.04 to 4.20
b Very inverse (VIT) and IEC VIT/B: 0.07 to 8.33
b Very inverse (LTI) and IEC LTI/B: 0.01 to 0.93
b Ext. inverse (EIT) and IEC EIT/C: 0.13 to 15.47
b IEEE moderately inverse: 0.42 to 51.86
b IEEE very inverse: 0.73 to 90.57
b IEEE extremely inverse: 1.24 to 154.32
b IAC inverse: 0.34 to 42.08
b IAC very inverse: 0.61 to 75.75
b IAC extremely inverse: 1.08 to 134.4.
(3) Only for standardized tripping curves of the IEC, IEEE and IAC types.
Block Diagram
pick-up signal and to
logic discrimination
DE80138
delayed output
EPATR-B curves
t EPATR-B tripping curves are defined from the following equations:
DE80070
85.386 T
b for Isr Ir 6.4 A - -------
t = --------------- -
I0 0.708 0.8
140.213 T
b if 6.4A Ir 200A - --------
= --------------------
0.975
I0 0.8
1 1
3 T
0.5
3
2
0.1
0.1 0.6 Isr 5 6.4 200 Ir
EPATR-B standard curve (log scales)
EPATR-C Curves
t EPATR-C tripping curves are defined from the following equations:
DE80071
b 72 T
for Isr Ir 200 A t = ----------- -----------
I0 2 / 3 2.10
Characteristics
Settings
Measurement Origin
Setting range Ir
I'r
Ir (sum of the main phase channels)
I'r (sum of the additional phase channels)
Tripping Curve
Setting range See previous page
Isr Setting
Definite time 0.01 INr Isr 15 INr (min. 0.1 A) expressed in amperes
Setting range Sum of CTs 0.01 IN Isr 15 IN (min. 0.1 A)
With CSH sensor
2 A rating 0.1 to 30 A
20 A rating 0.2 to 300 A
CT 0.01 INr Isr 15 INr (min. 0.1 A)
Zero sequence CT 0.01 INr Isr 15 INr (min. 0.1 A)
IDMT
Setting range
+ ACE990
0.01 INr Isr INr (min. 0.1 A) expressed in amperes 3
Sum of CTs 0.01 IN Isr IN (min. 0.1 A)
With CSH sensor
2 A rating 0.1 to 2 A
20 A rating 0.2 to 20 A
CT 0.01 INr Isr INr (min. 0.1 A)
Zero sequence CT 0.01 INr Isr INr (min. 0.1 A)
+ ACE990
EPATR CSH sensor 0.6 to 5 A
Setting range 20 A rating
Zero sequence CT 0.6 to 5 A
with ACE990 and
15 A INr 50 A
Accuracy (1) 5% or 0.004 In0
Resolution 1 A or 1 digit
Drop out/pick up ratio 93.5% 5% or > (1 - 0.005 INr/Isr) x 100%
Time Delay T (Operation Time at 10 Isr)
Setting range Definite time Inst, 50 ms T 300 s
IDMT 100 ms T 12.5 s or TMS (2)
EPATR-B 0.5 to 1 s
EPATR-C 0.1 to 3 s
Accuracy (1) Definite time 2% or from 10 ms to +25 ms
IDMT Class 5 or from 10 ms to +25 ms
Resolution 10 ms or 1 digit
Advanced Settings
2nd Harmonic Restraint
Fixed threshold 17% 3%
Timer Hold T1
Setting range Definite time 0; 0.05 to 300 s
IDMT (3) 0.5 to 20 s
Resolution 10 ms or 1 digit
Characteristic Times
Operation time Pick-up < 40 ms at 2 Isr (typically 25 ms)
Confirmed instantaneous:
b inst < 55 ms at 2 Isr for Is 0.3 INr (typically 35 ms)
b inst < 70 ms at 2 Isr for Is < 0.3 INr (typically 50 ms)
Overshoot time < 40 ms at 2 Isr
Reset time < 50 ms at 2 Isr (for T1 = 0)
x: unit number. Inputs
(1) Under reference conditions (IEC 60255-6). Designation Syntax Equations Logipam
(2) Setting ranges in TMS (Time Multiplier Setting) mode
b Inverse (SIT) and IEC SIT/A: 0.04 to 4.20 Protection reset P50N/51N_x_101 b b
b Very inverse (VIT) and IEC VIT/B: 0.07 to 8.33 Protection blocking P50N/51N_x_113 b b
b Very inverse (LTI) and IEC LTI/B: 0.01 to 0.93 Outputs
b Ext. inverse (EIT) and IEC EIT/C: 0.13 to 15.47 Designation Syntax Equations Logipam Matrix
b IEEE moderately inverse: 0.42 to 51.86
b IEEE very inverse: 0.73 to 90.57 Instantaneous output (pick-up) P50N/51N_x_1 b b
b IEEE extremely inverse: 1.24 to 154.32 Delayed output P50N/51N_x_3 b b b
b IAC inverse: 0.34 to 42.08 Drop out P50N/51N_x_4 b b
b IAC very inverse: 0.61 to 75.75 Protection blocked P50N/51N_x_16 b b
b IAC extremely inverse: 1.08 to 134.4.
15 A set point output P50N/51N_x_56 b b
(3) Only for standardized tripping curves of the IEC, IEEE and
IAC types.
b the customized curve, defined point by point, may be used with this protection
function
b an adjustable timer hold, definite time or IDMT, can be used for coordination
with electromagnetic relays and to detect restriking faults
b the set point is adjusted according to the lowest of the phase-to-phase
voltages measured. The adjusted set point I*s is defined by the following
equation:
b Set IDMT Trip Curves by Time delay T (at I/Iset = 10) or TMS Factor ( like Time
Dial Setting) - refer to topic "General Trip Curves at the end of this section
3 0.2 3 V LL N
Block Diagram
Vab
DE50841
Vbc
Vac
Ia/Ia
Ib/Ib
Ic/Ic
Characteristics
Settings
Measurement Origin
Setting range Main channels (I) / Additional channels (I)
Tripping Curve
Setting range See previous page
Is Set Point
Setting range Definite time 0.5 IN Is 24 IN expressed in amperes
IDMT 0.5 IN Is 2.4 IN expressed in amperes
Accuracy (1) 5%
Resolution 1 A or 1 digit
Drop out/pick up ratio 93.5% (with min. reset variance of 0.015 IN)
Time Delay T (Operation Time at 10 Is)
Setting range Definite time Inst, 50 ms T 300 s
IDMT 100 ms T 12.5 s or TMS (2)
Accuracy (1) Definite time 2% or from 10 ms to +25 ms
Resolution
IDMT
10 ms or 1 digit
Class 5 or from 10 ms to +25 ms
3
Advanced Settings
Timer Hold T1
Setting range Definite time 0; 0.05 to 300 s
IDMT time (3) 0.5 to 20 s
Resolution 10 ms or 1 digit
Characteristic Times
Operation time pick-up < 35 ms at 2 Is (typically 25 ms)
Inst. < 50 ms at 2 Is (confirmed instantaneous) (typically 35 ms)
Overshoot time < 50 ms
Reset time < 50 ms (for T1 = 0)
Inputs
Designation Syntax Equations Logipam
Protection reset P50V/51V_x_101 b b
Protection blocking P50V/51V_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P50V/51V_x_1 b b
Delayed output P50V/51V_x_3 b b b
Drop out P50V/51V_x_4 b b
Phase a fault P50V/51V_x_7 b b
Phase b fault P50V/51V_x_8 b b
Phase c fault P50V/51V_x_9 b b
Protection blocked P50V/51V_x_16 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
(2) Setting ranges in TMS (Time Multiplier Setting) mode
b Inverse (SIT) and IEC SIT/A: 0.04 to 4.20
b Very inverse (VIT) and IEC VIT/B: 0.07 to 8.33
b Very inverse (LTI) and IEC LTI/B: 0.01 to 0.93
b Ext. inverse (EIT) and IEC EIT/C: 0.13 to 15.47
b IEEE moderately inverse: 0.42 to 51.86
b IEEE very inverse: 0.73 to 90.57
b IEEE extremely inverse: 1.24 to 154.32
b IAC inverse: 0.34 to 42.08
b IAC very inverse: 0.61 to 75.75
b IAC extremely inverse: 1.08 to 134.4.
(3) Only for standardized tripping curves of the IEC, IEEE and IAC types.
Block Diagram
DE51551
Characteristics
3 Settings
Set Point Is
Setting range 0.02 IN to 2 IN with a minimum value of 0.05 A
Accuracy (1) 5%
Resolution 0.01 A
Drop out/pick up ratio 93.5%
Time Delay
Setting range 0.1 to 300 s
Accuracy (1) 2% or 25 ms
Resolution 10 ms or 1 digit
Characteristic Times (1)
Operation time Pick-up < 35 ms
Overshoot time < 35 ms
Reset time < 50 ms
Inputs
Designation Syntax Equations Logipam
Protection reset P51C_x_101 b b
Protection blocking P51C_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output P51C_x_1 b b
Tripping output P51C_x_3 b b b
Protection blocked P51C_x_16 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
DE51626
b in phase-to-neutral operation, it indicates the t Vca (or Vcn)
faulty phase in the alarm associated with the fault
Operation with phase-to-neutral or phase-to-phase Vab (or Van)
voltage depends on the connection selected for the
Vbc (or Vbn)
voltage inputs.
Vca (or Vcn) 3
Characteristics
Settings
Measurement Origin
Setting range Main channels (VLL) / Additional channels (VLL)
Voltage Mode
Setting range Phase-to-phase voltage / Phase-to-neutral voltage
VLLs (or VLns) Set Point
Setting range 50% of VLLp (or VLnp) to 150% of VLLp (or VLnp)
Accuracy (1) 2%
Resolution 1%
Drop out/pick up ratio 97% 1%
Time Delay T
Setting range 50 ms to 300 s
Accuracy (1) 2% or 25 ms
Resolution 10 ms or 1 digit
Characteristic Times
Operation time Pick-up < 40 ms from 0.9 VLLs (VLns) to 1.1 VLLs (VLns)
(typically 25 ms)
Overshoot time < 40 ms from 0.9 VLLs (VLns) to 1.1 VLLs (VLns)
Reset time < 50 ms from 1.1 VLLs (VLns) to 0.9 VLLs (VLns)
Inputs
Designation Syntax Equations Logipam
Protection reset P59_x_101 b b
Protection blocking P59_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P59_x_1 b b
Delayed output P59_x_3 b b b
Fault phase a (2) P59_x_7 b b
Fault phase b(2) P59_x_8 b b
Fault phase c(2) P59_x_9 b b
Protection blocked P59_x_16 b b
Instantaneous output Van or Vab P59_x_23 b b
Instantaneous output Vbn or Vbc P59_x_24 b b
Instantaneous output Vcn or Vca P59_x_25 b b
Delayed output Van or Vab P59_x_26 b b
Delayed output Vbn or Vbc P59_x_27 b b
Delayed output Vcn or Vca P59_x_28 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
(2)When the protection function is used for phase-to-neutral voltage.
The residual voltage is obtained by the vector sum of the phase voltages or by
measurements using delta connected VTs. The neutral point voltage is measured
by a VT inserted in the neutral point of the generator or the motor.
The protection function includes a time delay T, either definite or IDMT (dependent
on the residual voltage Vr) (see tripping curve equation on page 173).
Block Diagram
Van
3 Vbn
DE50785
Vcn
Vr > Vsr
Characteristics
Settings
Measurement Origin
Setting range Main channels (Vr)
Additional channels (Vr)
Neutral-point voltage (VLnt)
Tripping Curve
Setting range Definite time
IDMT (dependent on the residual voltage Vr)
Vsr Set Point
Definite time setting range 2% to 80% VLLp (for residual voltage Vr)
2% to 80% Vntp (for neutral point voltage Vnt)
IDMT setting range 2% to 10 % VLLp (for residual voltage Vr)
2% to 10 % Vntp (for neutral point voltage VLnt)
Accuracy (1) 2% or 0.005 VLLp
Resolution 1%
Drop out/pick up ratio 97% 2% or > (1 - 0.006 VLLp/Vsr) x 100%
Time Delay T (Tripping Time at 2 Vsr)
Definite time setting range 50 ms to 300 s
IDMT setting range 100 ms to 10 s
Accuracy (1) 2% or 25 ms
Resolution 10 ms or 1 digit
Characteristic Times
Operation time pick-up < 45 ms (typically 25 ms) at 2 Vsr
Overshoot time < 40 ms at 2 Vsr
Reset time < 40 ms at 2 Vsr
Inputs
Designation Syntax Equations Logipam
Protection reset P59N_x_101 b b
Protection blocking P59N_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P59N_x_1 b b
Delayed output P59N_x_3 b b b
Protection blocked P59N_x_16 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
DE50842
Description
The restricted ground fault protection function detects
phase-to-ground faults on three-phase windings with
grounded neutral. This function protects generators
and transformers.
0.05
IN
The function is based on the comparison of the residual current calculated using the
sum of the three phase currents and the neutral point current. These two currents
define the differential residual current and the restrained current:
b differential residual current: I 1r = I r I r
b restrained current or through residual current: the value of the restrained
current depends on detection of a fault outside the protected zone:
v without detection of an external fault
Ir0 = I r
v with detection of an external fault: the protection function is insensitive to
saturation of the CTs, but its operation is not blocked.
I r
Ir0 = 2 I r + ------
3
The function picks up if the differential residual current is greater than the operating
set point. The set point is defined by:
b the minimum set point Is0
b a tripping characteristic with a slope of 1.05 (differential residual current vs.
restrained current).
Block Diagram
Ir input (or Ir)
DE50843
The current transformer should be defined by which equation produces the highest
knee point voltage:
a. Vk (RCT + Rw) x 20 IN
b. Vk (RCT + Rw) ( 1.6 I3P /IN) x IN
c. Vk (RCT + Rw) ( 2.4 I1P /IN) x IN
The equations apply to the phase current transformers and the neutral-point current
transformer.
IN is the CT rated secondary current.
RCT is the CT internal resistance.
3
Rw is the resistance of the CT load and wiring.
I3P is the maximum current value for a three-phase short-circuit.
I1P is the maximum current value for a phase-to-ground short-circuit.
Characteristics
Settings
Measurement Origin
Setting range Main channels (I, Ir)
Additional channels (I, Ir)
Isr
Setting range 0.05 IN to 0.8 IN for IN 20 A
0.1 IN to 0.8 IN for In < 20 A
Accuracy (1) 5%
Resolution 1 A or 1 digit
Drop out/pick up ratio 93% 2%
Characteristic Times
Operation time < 55 ms at I1r = 2.1 Ir0
Overshoot time < 35 ms at I1r = 2.1 Ir0
Reset time < 45 ms at I1r = 2.1 Ir0
Inputs
Designation Syntax Equations Logipam
Protection reset P64REF_x_101 b b
Protection blocking P64REF_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Protection output P64REF_x_3 b b b
Protection blocked P64REF_x_16 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
Motor protection against heat rise caused The number of consecutive starts is the number starts counted during the last P/Nt
minutes.
overly frequent starts.
The motor hot state corresponds to the overshooting of the fixed set point (50% heat
rise) of the thermal overload function. During re-acceleration, the motor is subjected
Description to a stress similar to that of starting without the current first passing through a value
Protection against motor overheating caused by: less than 5% of IB. In this case, the number of starts is not incremented. It is however
b overly frequent starts: motor energizing is possible to increment the number of starts for a re-acceleration using a logic input or
blocked when the maximum permissible number information from a logic equation or Logipam program ("motor re-acceleration"
of starts is reached input).
b starts occur too close to one another: motor re-
energizing after a shutdown is allowed only after The "stop/start" time delay T may be used to block starting after a stop until the delay
an adjustable time delay. has elapsed and thus impose a minimum stop time before each restart.
Use of Circuit Breaker Closed Data
Starting is detected when the current drawn rises above In synchronous motor applications, it is advisable to connect the "circuit breaker
5% of current IB. closed" data to a logic input in order to enable more precise detection of starts.
The number of starts is limited by:
b the number of starts (Nt) allowed per period of User Information
3 time (P)
b the permissible number of consecutive hot starts
The following information is available for the user:
b the time before a start is allowed
b the number of starts still allowed.
(Nh)
See the section on machine diagnosis.
b the permissible number of consecutive cold
starts (Nc).
Block Diagram
Ia
DE50844
Ib I > 0.05 IB
Ic
k2 > Nc
D
E
5 k3 > Nh
0
8
4
4
Characteristics
Settings
Period of Time (P)
Setting range 1 to 6 hours
Resolution 1h
Total Number of Starts (Nt) Allowed per Period of Time (P)
Setting range 1 to 60
Resolution 1
Number of Consecutive Hot Starts (Nh)
Setting range 1 to Nf
Resolution 1
Number of Consecutive Cold Starts (Nc)
Setting range 1 to Nt
Resolution 1
Stop/start Time Delay
Setting range 0 to 90 min. (0 = no delay)
Resolution 1 min.
Inputs
Designation Syntax Equations Logipam
Protection reset P66_1_101 b b
Motor re-acceleration P66_1_102 b b
Protection blocking P66_1_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Protection output P66_1_3 b b b
Protection blocked P66_1_16 b b
Stop/start block P66_1_29 b b
Total number starts reached P66_1_30 b b
Total consecutive starts reached P66_1_31 b b
MT11128
Van Van Vab
current direction.
Vac
Vbn
Description
Vcn Ib
This function comprises a phase overcurrent function Vcn Vbn Vcn
associated with direction detection and picks up if the Ic Vbn
Vbc
phase overcurrent function in the chosen direction (line
or bus) is activated for at least one of the three phases
(or two of the three, depending on the settings).
b the protection function is 3-phase and has a Vab
DE50667
definite or IDMT time delay.
Ia
b each of the two units has two groups of settings.
Switching to setting group A or B can be carried
out by a logic input or remote control command,
depending on the settings.
b the customized curve, defined point by point, Vbc Ic
3
may be used with this protection function.
b an adjustable timer hold, definite time or IDMT, Ib
can be used for coordination with
electromagnetic relays and to detect restriking Vac
faults. Fault tripping in line zone with = 30
b the alarm linked to the protection function
indicates the faulty phase or phases.
Vab
Tripping Direction
DE50668
Vbc
Ib Ic
NO
Block Diagram
DE52315
A
A
A
B
3 Vca
B
B
C
C
C
phase a instantaneous
DE50849
DE80139
phase b instantaneous
phase c instantaneous
DE51628
DE52316
Characteristics 3
Settings
Characteristic Angle
Setting range 30, 45, 60
Accuracy (1) 2%
Tripping Curve
Setting range See list above
Is Set Point
Setting range definite time 0.1 IN Is 24 IN in amperes
IDMT 0.1 IN Is 2.4 IN in amperes
Accuracy (1) 5% or 0.01 IN
Resolution 1 A or 1 digit
Drop out/pick up ratio 93.5% 5% or > (1 - 0.015 IN/Is) x 100%
Time Delay T (Operation Time at 10 Is)
Setting range definite time Inst, 50 ms T 300 s
IDMT 100 ms T 12.5 s or TMS (2)
Accuracy (1) definite time (4) 2% or from 10 ms to +25 ms
IDMT Class 5 or from 10 ms to +25 ms
Resolution 10 ms or 1 digit
Advanced Settings
Tripping Direction
Setting range Bus / line
Tripping Logic
Setting range One out of three / two out of three
Timer Hold T1
Setting range definite time 0; 0.05 to 300 s
IDMT (3) 0.5 to 20 s
Resolution 10 ms or 1 digit
Characteristic Times
Operation time pick-up < 75 ms at 2 Is (typically 65 ms)
Inst. < 90 ms at 2 Is (confirmed
instantaneous) (typically 75 ms)
Overshoot time < 45 ms at 2 Is
Reset time < 55 ms at 2 Is (for T1 = 0)
Inputs
Designation Syntax Equations Logipam
Protection reset P67_x_101 b b
Protection blocking P67_x_113 b b
Outputs
x: unit number. Designation Syntax Equations Logipam Matrix
(1) Under reference conditions (IEC 60255-6). Instantaneous output (pick-up) P67_x_1 b b
(2) Setting ranges in TMS (Time Multiplier Setting) mode Delayed output P67_x_3 b b b
Inverse (SIT) and IEC SIT/A: 0.04 to 4.20
Very inverse (VIT) and IEC VIT/B: 0.07 to 8.33 Drop out P67_x_4 b b
Very inverse (LTI) and IEC LTI/B: 0.01 to 0.93 Instantaneous output (reverse P67_x_6 b b
Ext. inverse (EIT) and IEC EIT/C: 0.13 to 15.47 zone)
IEEE moderately inverse: 0.42 to 51.86 Phase a fault P67_x_7 b b
IEEE very inverse: 0.73 to 90.57 Phase b fault P67_x_8 b b
IEEE extremely inverse: 1.24 to 154.32
Phase c fault P67_x_9 b b
IAC inverse: 0.34 to 42.08
IAC very inverse: 0.61 to 75.75 Protection blocked P67_x_16 b b
IAC extremely inverse: 1.08 to 134.4. Instantaneous output at 0.8 Is P67_x_21 b b
(3) Only for standardized tripping curves of the IEC, IEEE and 1 out of 3 delayed output P67_x_36 b b
IAC types. 2 out of 3 delayed output P67_x_37 b b
NO
The tripping zone is set for tripping in the bus zone or in the line zone.
The reverse zone is the zone for which the protection function does not trip. The
detection of current in the reverse zone is used for indication.
capacitance using a tuned inductor in the neutral. This is not common in North
America).
The tripping direction may be set at the bus end or line end.
characteristic angle:
DE50455
r = 0? Each of the two units has two groups of settings. Switching to setting group A or B
can be carried out by a logic input or a remote control command, depending on the
settings.
sector
Vr
Memory
The detection of recurrent faults is controlled by the time delay T0mem which
extends the transient pick-up information, thereby enabling the operation of the
definite time delay even with faults that are rapidly extinguished ( 2 ms) and restrike
periodically. Even when a Petersen coil with no additional resistance is used, tripping
is ensured due to fault detection during the transient fault appearance. Detection is
Isr set point extended throughout the duration of the fault based on the criterion Vr Vr mem,
within the limit of T0mem. With this type of application, T0mem must be greater than
T (definite time delay).
tripping zone
Van
Vbn
DE80140
Vcn
Vr
r r r r r
CSH ZSCT Ir Ir r r
Ir
r Ir r r
pick-up signal and
Ir r r to zone selective
interlocking
Characteristics
Settings
Measurement Origin
Setting range Ir / Ir
Characteristic Angle
Setting range -45, 0, 15, 30, 45, 60, 90
Accuracy (1) 2
Isr Setting
Setting range 0.01 INr Isr 15 INr (min. 0.1 A)
in amperes
Sum of CTs 0.01 IN Isr 15 In (min. 0.1 A)
With CSH sensor 2 A rating 0.1 to 30 A
20 A rating 0.2 to 300 A
CT 0.01 INr Isr 15 INr (min. 0.1 A)
Zero sequence CT with ACE990 0.01 INr Isr 15 INr (min. 0.1 A)
Accuracy (1) 5% (at r = 180)
Resolution 1 A or 1 digit
Inst, 50 ms T 300 s
Accuracy (1) 2% or from -10 ms to +25 ms
Resolution 10 ms or 1 digit
Advanced Settings
Tripping Direction
Setting range Bus / line
Vsr Set Point
Setting range 2% to 80% VLLp
Accuracy (1) 5% or 0.005 VLLp
Resolution 1%
Drop out/pick up ratio 93.5% 5%
or > (1 - 0.006 VLLp/Vsr) x 100%
Sector
Setting range 86, 83, 76
Accuracy (1) 2
Memory Time Tr mem
Setting range 0; 0.05 to 300 s
Resolution 10 ms or 1 digit
Memory Voltage Vr mem
Setting range 0; 2 to 80% of VLLp
Resolution 1%
Characteristic Times
Operation time Pick-up < 55 ms at 2 Isr
Overshoot time < 45 ms at 2 Isr
Reset time < 50 ms (at Tr mem = 0)
Inputs
Designation Syntax Equations Logipam
Protection reset P67N_x_101 b b
Protection blocking P67N_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P67N_x_1 b b
Delayed output P67N_x_3 b b b
Drop-out P67N_x_4 b b
Instantaneous output (reverse zone) P67N_x_6 b b
Protection blocked P67N_x_16 b b
Instantaneous output at 0.8 Isr P67N_x_21 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6).
Standard Setting
The settings below are given for usual applications in different grounding systems.
The shaded boxes represent default settings.
Isolated neutral Impedant neutral Compensated
neutral
Isr setting Set according to Set according to Set according to
coordination study coordination study coordination study
Characteristic angle 0 90 0 0
Time delay T Set according to Set according to Set according to
coordination study coordination study coordination study
Direction Line Line Line
Vsr set point 2% of VLLs 2% of VLLs 2% of VLLs
Sector N/A 86 86
Memory time T0mem 0 0 200 ms
Memory voltage 0 0 0
V0mem
Vr The tripping direction may be set at the bus end or line end.
Each unit has two groups of settings. Switching to setting group A or B is carried out
Isr by a logic input or a remote control command, depending on the settings.
The customized curve, defined point by point, may be used with this protection
function. An adjustable timer hold, definite time or IDMT, can be used for
3
coordination with electromagnetic relays and to detect restriking faults.
Block Diagram
r
DE80141
CSH ZSCT
r Ir > 0.8 Isr
ZSCT + ACE990
Ir Ir > Isr
Van
Vbn
Vcn r r r
r r r
Vr
pick-up signal and
Vr Vr > Vsr to zone selective
interlocking
Ir Ir > Isr
Characteristics
Settings
Measurement Origin
Setting range Ir
Ir
Ir (sum of the main phase channels)
Characteristic Angle
Setting range -45, 0, 15, 30, 45, 60, 90
Accuracy (1) 2
Tripping Curve
Setting range See previous page
Isr Setting
Definite time 0.01 INr Isr 15 INr (min. 0.1 A)
setting range in amperes
Sum of CTs 0.01 IN Isr 15 IN (min. 0.1 A)
With CSH sensor 2 A rating 0.1 to 30 A
3 CT
20 A rating
Type 3 Operation
This protection operates like a ground fault protection function (ANSI 50N/51N) with
DE51173
Tripping zone Residual current is the current measured at the Sepam Ir input. It has a definite
time delay (DT constant).
By choosing "0" as an Isr set point, the protection function behaves like a neutral
voltage displacement protection function (ANSI 59N).
Simplified Schematic
3
DE80142
CSH ZSCT
ZSCT
+ ACE990
Van
Vbn
Vcn
pick-up signal and
to zone selective
interlocking
Isr Ir
Type 3 Characteristics
Measurement Origin
Setting range Ir
Ir
Ir (sum of the main phase channels)
Tripping Zone Start Angle Lim.1
Setting 0 to 359
Resolution 1
Accuracy 3
Tripping Zone End Angle Lim.2
Setting 0 to 359 (1)
Resolution 1
Accuracy 3
Tripping Direction
Setting Line/bus
Isr Set Point
(2 A rating)
With 1 A CT 0.005 INr Isr 15 INr (min. 0.1 A)
With zero sequence CT + 0.01 INr Isr 15 INr (min. 0.1 A) (3)
ACE990 (range 1)
Resolution 0.1 A or 1 digit
Accuracy 5%
Drop-out/pick-up ratio 95%
Vsr Set Point
Setting On sum of 3 Vs 2% VLLp Vsr 80% VLLp
On external VT 0.6% VLLp Vsr 80% VLLp
Resolution 0.1% for Vsr < 10%
1% for Vsr 10%
Accuracy 5%
Drop-out/pick-up ratio 95%
Time Delay T
Setting instantaneous, 50 ms T 300 s
Resolution 10 ms or 1 digit
Accuracy 3% or 20 ms at 2 Isr
Characteristic Times
Operation time pick-up < 40 ms at 2 Isr
instantaneous < 55 ms at 2 Isr
Overshoot time < 40 ms
Reset time < 50 ms
Inputs
Designation Syntax Equations Logipam
Reset protection P67N_x_101 b b
Block protection P67N_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P67N_x_1 b b
Delayed output P67N_x_3 b b b
Drop-out P67N_x_4 b b
Instantaneous output (reverse zone) P67N_x_6 b b
Protection blocked P67N_x_16 b b
Instantaneous output at 0.8 Is0 P67N_x_21 b b
(1) Tripping zone Lim.2-Lim.1 should be 10 or more.
(2) For Isr = 0, the protection function behaves like a neutral voltage displacement protection
function (59N).
(3) INr = k n where n = the zero sequence CT ratio and k = coefficient to be determined according
to the wiring of the ACE990 (0.00578 k 0.04).
Equal-Area Criterion
This function calculates the acceleration area when a fault appears and the braking
area when the fault disappears. The tripping command is issued if the braking area
is smaller than the acceleration area.
The function calculates an average power over four seconds (under steady state
conditions). This is called power before fault (Pbf) and corresponds to the electrical
power supplied by a generator or drawn by a motor. The function picks up when the
instantaneous power is different than Pbf.
3
A time delay is available to delay tripping. If a "return to stability" is detected during
the time delay, the function is reinitialized without tripping.
loss of synchronism:
start time delay
Power-Swing Criterion
This function detects a change in the active power sign.
Two power swings are counted for each 360 of phase displacement between the
electromotive force of the machine and the network. Power swings are detected by
comparing the sign of the instantaneous power with that of the power 14 ms before,
Pp. If the signs are different, a swing is counted.
The trip command is issued if the number of 360 displacements measured is equal
to the set number. A time delay may be used to set a maximum time between two
swings. This makes the function insensitive to low-frequency power oscillations.
DE50858
Current Transformers
Current transformers should be defined by a knee-point voltage
Vk (RCT + RW) 20 INS
where RCT: CT internal resistance
Rw: wiring resistance CT rated secondary current
Characteristics
Settings
Tripping Type Selection
Setting range Equal-area criterion
Power-swing criterion
Equal-area criterion and power-swing criterion
Equal-Area Criterion Time Delay
Setting range 100 ms T 300 s
Accuracy (1) 2% or from 10 ms to +25 ms
Resolution 10 ms or 1 digit
Number of 360 Displacements
Setting range 1 number of 360 displacements 30
Accuracy (1)
Resolution 1 360 displacement
Maximum Time Between Two 360 Displacements
Setting range 1 s T 300 s
Accuracy (1) 2% or from 10 ms to +25 ms
Resolution 1 s or 1 digit
Characteristic Times
Operation time 38 ms to 2 Ps (2)
Inputs
Designation Syntax Equations Logipam
Protection reset P78PS_1_101 b b
Protection blocking P78PS_1_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P78PS_1_1 b b
Delayed output P78PS_1_3 b b b
Protection blocked P78PS_1_16 b b
(1) Under reference conditions (IEC 60255-6).
(2) Ps = the maximum number of Poles slipped.
Example of Setting The electrical power supplied by the machine to the network is: Pe = 3VI pf .
Consider a 3.15 MVA generator in an industrial P
installation, connected to a network with a high short- On the vector diagram: E sin = X d ( I pf ) = X d -------e .
3V
circuit. Protection against losing synchronization is set
up to trip according to the equal-area criterion and the As a function of the electromotive force, the internal angle and the synchronous
power-swing criterion. 3VE sin
reactance, the active power is: Pe = ------------------------- .
b tripping according to the equal-area criterion: Xd
300 ms This equation can be used to determine the electrical power supplied by the
b number of 360 displacements allowed: 2 generator to the network, as a function of the internal angle and assuming that V, E
b the maximum time between two swings is 10 and Xd are constant.
seconds. If losses are neglected (efficiency is close to 0.99), the relation between the
mechanical power Pm and the electrical power supplied Pe is:
Principle of Transient Stability d
Pm = Pe + J --------
There are three types of stability in an electrical network: dt
b steady state stability concerns small variations in where J is the moment of inertia of the machine
load and power. It is monitored by the power is the angular velocity of the rotating masses
Pm is the mechanical power supplied by the driving machine
regulation functions
b dynamic stability concerns larger variations. It is
ensured by the network regulation functions The velocity of the electric field is related to the mechanical velocity by the equation:
3
b transient stability concerns major variations in
= ----
power, such as during faults. It is monitored by p
action on the network, such as load shedding, where is the angular velocity of the electrical field
source disconnection or independent operation p is the number of pole pairs in the machine
of certain zones in the network.
In the remainder of this example, we will consider a machine with a single pair of
poles, i.e. p = 1.
Protection against synchronism loss can be used to
detect cases of transient instability. The relation between electrical and mechanical power becomes:
When a generator is connected to a network that has d
Pm = Pe + J -------- .
infinite power, the voltage across its terminals is dt
imposed by the network. For a turbo-generator under Variations in speed are directly related to unbalances between the mechanical power
steady state conditions, the internal impedance is equal and the electrical power supplied to the network.
to its longitudinal synchronous reactance Xd (the d Pm Pe
resistance and possible saturation of the magnetic -------- = ------------------- .
dt J
circuit are not factors).
Under steady state conditions (with no increase in speed), the electrical power (Pe)
supplied to the network is equal to the mechanical power (Pm).
DE50639
DE50641
V = E jXdI
where E is the electromotive force of the machine
Power
dt J
System The machine slows as long as the electrical power supplied is not equal to the
Rotation
mechanical power, because the derivative of the velocity is negative. Electrically
speaking, the electromotive force reduces its lead and consequently the angle .
v if decreases slightly with respect to its value at point A (the electromotive
force reduces its lead on the network voltage), the electrical power
supplied to the network decreases slightly. At a constant level of
mechanical power:
d Pm Pe
-------- = ------------------- >0.
dt J
The machine accelerates as long as the electrical power supplied is not equal to the
mechanical power, because the derivative of the velocity is positive. Electrically
speaking, the electromotive force increases its lead and consequently the angle .
DE50859
consequently the angle .
v if decreases slightly with respect to its
value at point B (the electromotive force
reduces its lead on the network voltage), the
electrical power supplied to the network
increases slightly. At a constant level of
3 d
mechanical power:
Pm Pe
-------- = ------------------- <0.
dt J
The machine slows because the derivative of the
velocity is negative. Electrically speaking, the
electromotive force reduces its lead and consequently
the angle until it returns to point A.
b fault clearing and loss of synchronization
When the machine passes point B, racing occurs.
During slowing, the machine passes point B and begins to accelerate again because
When a fault occurs, assuming it is a three-phase dead
beyond this point, Pm - Pe(t) > 0.
short across the generator terminals, the voltage t2
across the machine terminals is equal to zero.
Consequently, the electrical power supplied to the
The braking area (P
t1
m Pe ( t )) dt is not sufficient.
network is zero:
The machine starts to race and stability is lost. The machine alternates between
3VE sin 3 0 E sin phases during which it supplies electrical power and others where it draws power.
Pe = ------------------------- = ------------------------------------ = 0 .
Xd Xd
The regulation systems do not have enough time to
react and the mechanical power across the machine
DE50860
1
d = --- Pm dt where
J
0 t0
of the machine.
1
d = --- ( Pm P e ( t ) ) dt
J
1 t1
Reclaim Time The recloser is ready to operate if all of the following conditions are met:
The reclaim time is activated by a circuit breaker b "switchgear control" function activated and recloser in service (not blocked by
closing command given by the recloser. If no faults are the recloser blocking logic input)
detected before the end of the reclaim time, the initial b circuit breaker closed
fault is considered to be cleared. Otherwise a new b the safety time is not running
reclosing step is initiated. b none of the recloser blocking conditions is true (trip circuit fault, control fault,
SF6 pressure drop)
The delay must be longer than the longest reclosing
Recloser Steps
step activation condition.
The recloser will step under any of the following conditions:
Safety Time until Ready b case of a fault that is not cleared: following instantaneous or time-delayed
The safety time is activated by a manual circuit breaker
closing command. The recloser is blocked for the
duration of the time. If a fault occurs during this time,
tripping by the protection unit, activation of the dead time associated with the
first active cycle. At the end of the dead time, a closing command is given,
which activates the reclaim time. If the protection unit detects the fault before
3
no reclosing steps are initiated and the circuit breaker the end of the time delay, a tripping command is given and the following
remains permanently open. reclosing step is activated. After all the active shots have run, a final trip
Dead Time command is given if the fault still persists and a message will appear on the
Step n dead time is launched by breaking device display
tripping command given by the recloser during step n. b case of a cleared fault: Following a reclosing command, if the fault does not
The breaking device remains open throughout the time. appear after the reclaim time has run out, the recloser reinitializes and a
At the end of the step n dead time, the n+1 step begins, message appears on the display (see example 1)
and the recloser commands the circuit breaker closed. b closing on a fault. If the circuit breaker closes on a fault, or if the fault appears
before the end of the safety time delay, the recloser is blocked. A final trip
message is issued
Recloser Block Conditions
The recloser is blocked according to the following conditions:
b voluntary open or close command
b recloser put out of service
b receipt of a block command on the logic input
b activation of the breaker failure, such as trip circuit fault, control fault, SF6
pressure drop
b opening of the circuit breaker by a protection unit that does not run reclosing
cycles (such as frequency protection), by external tripping or by a function set
up not to activate reclosing cycles.
In such cases, a final trip message appears.
Extending the dead time
If, during a reclosing step, it is impossible to reclose the circuit breaker because
recharging is not finished(1), the dead time can be extended up to the time the circuit
breaker is ready to carry out an "Open-Close-Open" cycle. The maximum time added
to the dead time is adjustable (Twait_max). If, at the end of the maximum waiting
time, the circuit breaker is still not ready, the recloser is blocked (see example 5).
Characteristics
Settings
Number of Steps
Setting range 1 to 4
Activation of Shot 1
Protection 50/51 units 1 to 4 inst. / delayed / no activation
Protection 50N/51N units 1 to 4 inst. / delayed / no activation
Protection 67 units 1 to 2 inst. / delayed / no activation
Protection 67N/67NC units 1 to 2 inst. / delayed / no activation
Logic equations or Logipam outputs active/inactive
V_TRIPCB
Activation of Shots 2, 3, and 4
Protection 50/51 units 1 to 4 inst. / delayed / no activation
Protection 50N/51N units 1 to 4 inst. / delayed / no activation
Protection 67 units 1 to 2 inst. / delayed / no activation
Protection 67N/67NC units 1 to 2 inst. / delayed / no activation
Logic equations or Logipam outputs active/inactive
3 V_TRIPCB
Time Delays
Reclaim time 0.1 to 300 s
Dead time Shot 1 0.1 to 300 s
Shot 2 0.1 to 300 s
Shot 3 0.1 to 300 s
Shot 4 0.1 to 300 s
Safety time until ready 0 to 60 s
Maximum additional dead time 0.1 to 60 s
Accuracy (2) 2% or 25 ms
Resolution 10 ms
Inputs
Designation Syntax Equations Logipam
Protection blocking P79_1_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Recloser in service P79 _1_201 b b b
Recloser ready P79 _1_202 b b b
Cleared fault P79 _1_203 b b b
Final trip P79 _1_204 b b b
Closing by recloser P79 _1_205 b b
Reclosing step 1 P79 _1_211 b b b
Reclosing step 2 P79 _1_212 b b b
Reclosing step 3 P79 _1_213 b b b
Reclosing step 4 P79 _1_214 b b b
(1) Under reference conditions (IEC 60255-6).
Cycle 2, ground
Ground fault Ground fault
fault message
Ground fault
The frequency is calculated using voltage Van or Vab when only one voltage is
connected. Otherwise the positive sequence voltage V1 is used to procure greater
stability. It is compared to the Fs set point.
The protection function is blocked if the voltage used for calculations is under the
adjustable set point Vs.
Block Diagram
DE50791
3
Characteristics
Settings
Measurement Origin
Setting range Main channels (VLL) / Additional channels (VLL)
Fs Set Point
Setting range 50 to 55 Hz or 60 to 65 Hz
Accuracy (1) 0.01 Hz
Resolution 0.1
Pick up / drop out difference 0.25 Hz
Time Delay T
Setting range 100 ms to 300 s
Accuracy (1) 2% or 25 ms
Resolution 10 ms or 1 digit
Advanced Settings
Vs Set Point
Setting range 20% to 50% VLLN
Accuracy (1) 2%
Resolution 1%
Characteristic Times
Operation time Pick-up < 90 ms from Fs -0.5 Hz to Fs +0.5 Hz
Overshoot time < 50 ms from Fs -0.5 Hz to Fs +0.5 Hz
Reset time < 55 ms from Fs +0.5 Hz to Fs -0.5 Hz
Inputs
Designation Syntax Equations Logipam
Protection reset P81H_x_101 b b
Protection blockingblock P81H_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P81H_x_1 b b
Delayed output P81H_x_3 b b b
Protection blockblocked P81H_x_16 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6) and df/dt < 3 Hz/s.
The frequency is calculated using voltage Van or Vab when only one voltage is
connected. Otherwise the positive sequence voltage V1 is used to provide greater
stability. It is compared to the frequency set point, Fs.
The protection function is blocked if the value of voltage used for calculations is
below the adjustable set point Vs.
Protection stability is provided in the event of the loss of the main source and
presence of remnant voltage by a restraint in the event of a continuous decrease of
the frequency.
Vab
Characteristics
Settings
Measurement Origin
Setting range Main channels (VLL) / Additional channels (VLL)
Fs Set Point
Setting range 40 to 50 Hz or 50 to 60 Hz
Accuracy (1) 0.01 Hz
Resolution 0.1
Pick up / drop out difference 0.25 Hz
Time Delay T
Setting range 100 ms to 300 s
Accuracy (1) 2% or 25 ms
Resolution 10 ms or 1 digit
Advanced Settings
Vs Set Point
Setting range 20% to 50% VLLN
Accuracy (1) 2%
Resolution 1%
Restraint on Frequency Variation
Setting With / without
dFs/dt set point 1 Hz/s to 15 Hz/s
Accuracy (1) 1 Hz/s
Resolution 1 Hz/s
Characteristic Times
Operation time Pick-up < 90 ms from Fs +0.5 Hz to Fs -0.5 Hz
Overshoot time < 50 ms from Fs +0.5 Hz to Fs -0.5 Hz
Reset time < 55 ms from Fs -0.5 Hz to Fs +0.5 Hz
Inputs
Designation Syntax Equations Logipam
Protection reset P81L_x_101 b b
Protection blockingblock P81L_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P81L_x_1 b b
Delayed output P81L_x_3 b b b
Protection blocked P81L_x_16 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6) and df/dt < 3 Hz/s.
Block Diagram
3
de51554
V1
Characteristics
Settings
dfs/dt Set Point
Setting range 0.1 to 10 Hz/s
Accuracy (1) 5% or 0.1 Hz
Resolution 0.01 Hz
Drop out/pick up ratio 93%
Temporization
Setting range 0.15 to 300 s
Accuracy (1) 2% or -10% +25 ms
Resolution 10 ms or 1 digit
Characteristic Times (1)
Operation time Pick-up < 150 ms (typically 130 ms)
Overshoot time < 100 ms
Reset time < 100 ms
Inputs
Designation Syntax Equations Logipam
Protection reset P81R_x_101 b b
Protection blockingblock P81R_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Instantaneous output (pick-up) P81R_x_1 b b
Tripping output P81R_x_3 b b b
Protection blocked P81R_x_16 b b
Invalid voltage P81R_x_42 b b
Invalid frequency P81R_x_43 b b
Positive df/dt P81R_x_44 b b
Negative df/dt P81R_x_45 b b
x: unit number.
(1) Under reference conditions (IEC 60255-6) and df/dt < 3 Hz/s.
Disconnection Application
The rate of change of frequency (df/dt) function can be used on service entrance
mains that include generators that operate in parallel with the utility grid. If, under
these conditions, the utility experiences an outage, the co-gen will temporarily try to
back feed the utility system. If the power flow from the utility prior to the service
switchgear main was not a zero value, the generator frequency changes.
The df/dt protection function detects an islanded generator operation more rapidly
than conventional frequency Protection Functions.
Other disturbances such as short-circuits, load fluctuations and switching may cause
changes of frequency. The low set point may be reached temporarily due to these
disturbances and a time delay is necessary. In order to maintain the advantage of the
speed of the df/dt protection (compared to conventional frequency protection
functions), a second, higher set point with a short time delay may be added.
The actual rate of change of frequency is not constant. Often, the rate is highest at
3 the beginning of the disturbance and decreases afterward. This extends the tripping
time of frequency protection functions but does not affect the tripping time of the rate
of change of frequency protection function.
Low Set Point
b Follow the utility's instructions, if there are any.
b If there are no utility instructions, proceed as follows:
v if the maximum rate of change of frequency on the network under normal
conditions is known, dfs/dt should be set above it.
v if no information on the network is available, the low set point may be set
according to generator data.
A good approximation of the rate of change of frequency after a utility
failure resulting in a load variation P is:
df P fn where Sn: rated power
------ = ---------------------------- fn: rated frequency
dt 2 Sn H
H: inertia constant
Typical value of the inertia constant (in MWs/MVA):
0.5 H 1.5 for diesel and low-power generators ( 2 MVA)
2 H 5 for gas turbines and medium-power generators ( 40 MVA)
J 2 where J: moment of inertia
H = ----------------- : machine speed
2 Sn
Examples
Rated power 2 MVA 20 MVA
Inertia constant 0.5 MWs/MVA 2 MWs/MVA
Power variation 0.1 MVA 1 MVA
df/dt 2.5 Hz/s 0.6 Hz/s
Operating Precautions:
When the generator connects to the network, power oscillations may occur until the
generator becomes fully synchronized. The df/dt protection function senses this
phenomenon, so it is advisable to block the protection unit for a few seconds after
circuit breaker closing.
According to the current measurement convention, shown in the diagram and respecting
Description the recommended wiring system, the differential and through currents are calculated by:
This is phase-to-phase short-circuit protection and is b differential current:
based on phase by phase comparison of the currents Idx = I x + I x where x = a, b, c
on motor and generator windings. b through current
This function enables if the difference in current is I x I x
- where x = a, b, c
Itx = -------------------
greater than the set point defined by: 2
b a percentage-based curve
The percentage-based characteristic is made up to two half curves defined according
b a differential curve (high set point).
to the following formulas:
b 1st half curve depending on the Is set point
Tripping restraint ensures stability due to:
b detection of an external fault or machine starting 2
2
Itx > Is2 where 0 Itx 2IN and x = a, b, c
3 b detection of CT saturation
b fast detection of CT loss
b
Idx -----------
32
2nd half curve
b detection of transformer energizing.
2 2
Idx Itx > ( 0.005 I N ) 2 where 2IN < Itx and x = a, b, c.
------------- -----------
8 32
Ia Ib Ic Ic Ib Ia
DE50311
DE52189
Tripping Restraints
The following are applications for machine differential restraint:
1 Restraint for external faults or machine starting
During starting or an external fault, the through current is much higher than 1.5 IN.
As long as the CTs do not saturate, the differential current is low. This transient state
is detected by the following characteristic:
2 2
Idx Itx
------------- ----------- < ( 0.25 I N )
2
where x = a, b, c
2 32
An external fault can be followed by a short, but high differential current, that is why
a 200 ms restraint is used to ensure protection stability for this type of fault.
2 Restraint on CT saturation
CT saturation can result in a false differential current and nuisance tripping. The
restraint analyses the asymmetry of the signals and restrains the tripping command
if a CT is saturated.
3 Restraint on CT loss
CT loss can result in a false differential current and nuisance tripping. This restraint 3
is the means to detect a measurement that abnormally drops to zero (sample
analysis).
Block Diagram
DE52288
Generators are characterized by large X/R ratio's. The rule of thumb is to use the
highest possible accuracy class. A completely offset short circuit current requires the
ct to support (1+X/R) times the calculated voltage. In many applications it is not
possible to completely avoid saturation. Under these conditions it is helpful to have
machine differential ct's with the same knee point voltage.
The equations apply to the phase current transformers placed on either side of the
machine.
3 The setting range of the Is set point depends on the rated values of the CTs on the
main channels Ia, Ib, Ic and the additional channels I'a, I'b, I'c. The setting range is
the intersection of [0.05 IN 0.5 IN] with [0.05 IN 0.5 IN]. When the rated values are
identical, the setting range is optimum. If there is no intersection, the function cannot
be used.
Characteristics
Settings
Is Set Point
Setting range max (0.05 INA; 0.05 INB) Is min (0.5 INa; 0.5 INB)
Accuracy (1) 5% Is or 0.4% IN
Resolution 1 A or 1 digit
Drop out/pick up ratio 93.5%
Advanced Settings
Pick-up of restraint on CT loss
Setting range On / off
Characteristic Times
Operation time Operation time of differential current function
Overshoot time < 40 ms
Reset time < 35 ms
Inputs
Designation Syntax Equations Logipam
Protection reset P81L_x_101 b b
Protection blockingblock P81L_x_113 b b
Outputs
Designation Syntax Equations Logipam Matrix
Protection output P87M_1_3 b b b
Phase a fault P87M_1_7 b b
Phase b fault P87M _1_8 b b
Phase c fault P87M _1_9 b b
Protection blocked P87M_1_16 b b
High set point P87M_1_33 b b
Percentage-based set point P87M_1_34 b b
CT loss P87M_1_39 b b
(1) Under reference conditions (IEC 60255-6).
Phase-to-phase short-circuit According to the current measurement convention shown in the diagram and
protection for transformers respecting the recommended wiring system, the differential currents Id and through
currents It are calculated using the matched currents Im and Im.
and transformer-machine units (2 windings) b Differential current: Idx = I xm + Ixm where x = a, b, or c
b Through current: Itx = max ( I xm , Ixm ) where x = a, b, or c
The function picks up if the differential current of at least one phase is greater than
Operation the operating threshold defined by:
This protection function protects the zone between the b a high adjustable differential current set point, without tripping restraint
CTs for the main currents Ia, Ib, Ic on the one hand and b an adjustable percentage-based characteristic with two slopes
the CTs for the additional currents I'a, I'b, I'c on the b a low adjustable differential current set point.
other.
Stability is ensured by the following tripping restraints:
It adjusts both the amplitude and phase of the currents b a self-adaptive or conventional harmonic restraint
in each winding according to the vector shift and the b a transfomer-energization restraint
transformer rated power, as well as the set voltage and b a CT-loss restraint.
current values. The high tripping set point is not restrained.
Block Diagram
DE52173
Ia
Ib
Ic
Ia
Ib
Ic
Ia
Ib
Ic
Ia
Ib
Ic
Ia
Ib
Ic
Ia
Ib
Ic
Definitions Matching
The terms winding 1 and winding 2 are used in the Principle
following manner: The currents in windings 1 and 2 cannot be compared directly due to the
b winding 1: corresponds to the circuit to which the transformation ratio and the phase displacement introduced by the power
main currents Ia, Ib, Ic, and the voltage transformer.
measurements Van, Vbn, Vcn, Vab, or Vbc are
connected Sepam does not use matching CTs. It uses the rated power and winding voltage
b winding 2: corresponds to the circuit to which the data to calculate the transformation ratio and, therefore, to match current amplitude.
additional currents I'a, I'b, I'c are connected. The vector shift is used to match the phase currents.
shows:
b the transformer rated current value for windings I2 Ia + I b + I c
I 2m = --------- ----------------------------------
1 and 2: IN1, IN2 IN1 3I N 1
b the value set on the "CT-VT" screen for the base
current IB of winding 1
Ic Ia + I b + I c
b the value calculated using the transformation I 3m = --------- ----------------------------------
IN1 3I N 1
ratio for the base current I'B of winding 2.
Standard IEC 60076-1 assumes the vector shift is given for a transformer connected
to a power source with a phase-rotation sequence of a-b-c. Sepam uses this vector
shift value for both a-b-c and a-c-b type networks.
Therefore, it is unnecessary to complement this value by a-b for an a-c-b type network.
When the current transformer connections are correct. The vector shift matching is the
result of the phase-displacement measurement taken by Sepam between the
currents in winding 1 and winding 2, divided by 30.
The table on the next page contains vectorial diagrams and matching formulae
based on the vector shift of the transformer for networks with type a-b-c phase-
rotation sequences.
DE52029
DE52028
DE52035
I a I a + I b + Ia + Ib + Ic
Ia + ----------------------------------
= --------- ------------------------ am = --------
-
IN2 3I N 2 IN2 3I N 2
3
0 I b I a + I b + 6
bm = --------
-
Ia + Ib + Ic
Ib + ----------------------------------
= --------- ------------------------
IN2 3I N 2 IN2 3I N 2
Ia + Ib + Ic
Ic + ----------------------------------
Icm = --------
-
IN2 3I N 2
I c I a + I b +
= --------- -------------------------
IN2 3I N 2
Ia Ib Ib Ia
Iam = -------------------- Iam = --------------------
DE52028
DE52030
DE52028
DE52036
3I N 2 3I N 2
Ib Ic Ic Ib
1 Ibm = -------------------- 7 Ibm = --------------------
3I N 2 3I N 2
Ic Ia Ia Ic
Icm = -------------------- Icm = --------------------
3I N 2 3I N 2
DE52028
DE52031
DE52028
DE52037
Ic Ia
Ib Ia + Ib Ib Ia + Ib + Ic
Ib --------- + ---------------------- am = --------- ----------------------------------
IN2 3I N 2 IN2 3I N 2
Ic Ib Ib Ic
Iam = -------------------- Iam = --------------------
DE52028
DE52032
DE52028
DE52038
3I N 2 3I N 2
3 Ia Ic 9 Ic Ia
Ibm = -------------------- Ibm = --------------------
3I N 2 3I N 2
Ib Ia Ia Ib
Icm = -------------------- Icm = --------------------
2 Ic Ia +3IIb N2 8 Ic 3IIa N 2 + Ib + Ic
--------- + ---------------------- bm = --------- ----------------------------------
IN2 3I N 2 IN2 3I N 2
DE52028
DE52033
DE52028
DE52039
Ic Ia + Ib + Ic + Ia + Ib + Ic
= --------- ------------------------ am = --------
- ----------------------------------
IN2 3I N 2 IN2 3I N 2
3
Ia + Ia + Ib Ia
cm = --------- Ia + Ib + Ic
- ----------------------
-------- ----------------------------------
IN2 3I N 2 IN2 3I N 2
Ia
4 Ibm = --------- Ia + Ib + Ic
---------------------------------- 10
IN2 3I N 2
Ia + Ia
bm = --------
+ Ib + Ic
- ----------------------------------
IN2 3I N 2
Ib Ia + Ib +
= --------- ------------------------
IN2 3I N 2
Ia + Ib + Ic
Ib + ----------------------------------
Icm = --------
-
IN2 3I N 2
Ic Ia Ia Ic
Iam = -------------------- Iam = --------------------
DE52028
DE52034
DE52028
DE52040
3I N 2 3I N 2
Ia Ib Ib Ia
5 Ibm = -------------------- 11 Ibm = --------------------
3I N 2 3I N 2
Ib Ic Ic Ib
Icm = -------------------- Icm = --------------------
3I N 2 3I N 2
Test Mode
Two operating modes facilitate maintenance and startup operations:
b normal mode: the protection function controls the tripping and
indication outputs based on the settings. This is the standard
operating mode
b test mode: the protection function controls tripping and
indication outputs based on test mode settings. This mode is
accessed only by the SFT2841 software, once it is connected
and the Protection setting password entered. The system
returns to normal mode when the software is disconnected
Note : Transfer from normal mode to test mode can result in
nuisance tripping if the protected transformer is
energized.
Test mode settings:
S
b V LL N 1 = ----------------
IN x 3
S
b V LL N 2 = -----------------
IN x 3
b vector shift = 0
DE52174
Self-Adaptive Restraint
The self-adaptive restraint is particularly suitable for transformers, where:
^Iinr < 8--- ^I2 N = 8I N
2
where inr is the peak tripping current
N is the rated peak current
IN is the rated transformer current
This neutral network restraint ensures stability in the event of an external fault by
analyzing the second- and fifth-harmonic factors, the differential currents and the
through currents. It ensures stability in the event of the following:
b transformer closing
b an asymmetrical fault outside the zone that saturates the CTs
b the transformer operating on a voltage supply that is too high (overexcitation).
Detecting the presence of harmonics and monitoring the through and differential
currents, the restraint automatically increases the low set point and the percentage-
based slopes. It is also more sensitive than the high set point.
Using the high set point is unecesseary when this restraint is active. Also, as the
restraint integrates the stabilization slope for high through currents (which can
saturate the CTs), slope Id/It2 does not have to be activated.
Conventional Restraint
The conventional restraint comprises a second-harmonic set point for each phase
and a fifth-harmonic set point for each phase.
The second-harmonic set point ensures that the protection function will not pick up if
the transformer closes or the CTs become saturated. The restraint can be global
(cross-blocking: all three phases are restrained as soon as the harmonic in one
phase exceeds the set point) or phase-specific (no cross-blocking: only the phase
with a harmonic exceeding the set point is restrained). Cross-blocking is
recommended for transformers used in three-phase mode.
The fifth-harmonic set point ensures that the protection function will not pick up if the
transformer is connected to a voltage supply that is too high. The restraint can be
global (all three phases are restrained) or phase-specific (only the phase with a
harmonic exceeding the set point is restrained). Restraint without cross-blocking is
recommended for normal operation.
Restraint on Closing
In some cases, the harmonic content of the transformer inrush current is not
sufficient to activate harmonic restraints. An additional restraint can be activated:
b when the through current exceeds an adjustable set point Isinr
b by an internal variable, P87T_1_118, controlled by logic equations or
Logipam.
This restraint is applied to the percentage-based differential elements for an
adjustable time period T. It is not applied to the high set point.
DE52175
3 Restraint on CT Loss
CT loss can distort the differential current and cause nuisance tripping. This restraint
detects a measurement dropping to zero abnormally by analyzing sampled
differential and through currents.
rule:
S S
b for winding 1: 0.1 x ----------------------------- y I N y 2.5 x -----------------------------
V LL n 1 x 3 V LL n 1 x 3
S S
b for winding 2: 0.1 x ----------------------------- y I N y 2.5 x -----------------------------
V LL n 2 x 3 V LL n 2 x 3
where:
IN is the primary rated current of the CT.
iN is the secondary rated current of the CT.
RCT is the internal resistance of the CT.
Rw is the resistance of the wiring and the CT load.
Characteristics
Settings
Low Set Point Ids
Setting range 30% to 100% of IN1
Accuracy (1) 2%
Resolution 1%
Drop-out/pick-up ratio 93.5% 5%
Percentage-Based Characteristic Id/It
Setting range 15% to 50%
Accuracy (1) 2%
Resolution 1%
Drop-out/pick-up ratio 93.5% 5%
Percentage-Based Characteristic Id/It2
Setting range None, 50% to 100%
Accuracy (1) 2%
Resolution 1%
Drop-out/pick-up ratio 93.5% 5%
Slope Change Point
Setting range
Accuracy (1)
None, IN1 to 18 IN1
5%
3
Resolution 0.1 INa
Drop-out/pick-up ratio 93.5% 5%
Test Mode
Setting range Active/Not active
Advanced Settings
Selection of restraint Conventional/Self-adaptive
Restraint on CT Loss
Setting range Active/Not active
Restraint on Closing
Setting range Active/Not active
Magnetization Setting range 1% to 10%
current set point Accuracy (1) 5%
Isinr Resolution 1%
Drop-out/pick-up ratio 90% 5% or 0.5% IN1
Time delay Setting range 0 to 300 s
Accuracy (1) 2% or -10 ms to +25 ms
Resolution 10 ms
High Set Point Idmax
Setting range Conventional restraint 3 to 18 IN1
Self-adaptive restraint None, 3 to 18 IN1
Accuracy (1) 2%
Resolution 1%
Drop-out/pick-up ratio 93.5% 5%
Second-Harmonic Set Point for Conventional Restraint
Setting range None, 5 to 40%
Accuracy (1) 5%
Resolution 1%
Drop-out/pick-up ratio 90% 5%
Second-Harmonic Restraint for Conventional Restraint
Setting range Phase-specific/Global
Fifth-Harmonic Set Point for Conventional Restraint
Setting range None, 5 to 40%
Accuracy (1) 5%
Resolution 1%
Drop-out/pick-up ratio 90% 5%
Fifth-Harmonic Restraint for Conventional Restraint
Setting range Phase-specific/Global
Characteristic Times
Operating time high set point < 45 ms at 2 Id
Operating time percentage-based curve < 45 ms at 2 Id
Reset time < 45 ms at 2 Id
Inputs
Designation Syntax Equations Logipam
Protection reset P87T_1_101 b b
Protection blocking P87T_1_113 b b
Restraint on closing P87T_1_118 b b
Outputs
Designation Syntax Equations Logipam Matrix
Protection output P87T_1_3 b b b
Protection blocked P87T_1_16 b b -
High set point P87T_1_33 b b -
Percentage-based threshold P87T_1_34 b b -
CT loss P87T_1_39 b b -
(1) Under reference conditions (IEC 60255-6). Test mode P87T_1_41 b b -
Example 1
4 MVA, Dyn11, 20 kV/1 kV transformer, the peak closing current is: ^Iinr = 5^IN
DE52177
The transformer operates normally at its rated load, but will tolerate operation at up
to 120% of its rated power.
Sensor selection
The rated current of the windings is:
S 4 MVA S 4 MVA
I N 1 = --------------------- = ------------------- = 116 A and I N 2 = --------------------- = ------------------ = 2.3 kA
3VLLN1 320 kV 3VLLN2 31 kV
The CTs can support an overload of 120%:
IN > 116 A x 1.2 = 139.2 A and I'n > 2.3 kA x 1.2 = 2.76 kA
The main currents of the CTs must also meet the following requirements:
S S S S
0.1 --------------------- y In y 2.5 --------------------- and 0.1 --------------------- y In y 2.5 ---------------------
3VLLN1 3VLLN1 3VLLN2 3VLLN2
IN = 150 A and IN = 3 kA
The tripping current is ^Iinr = 5^IN , so, for both winding 1 and winding 2:
^Iinr1 = 5 x 2 x 116 A = 820 A
^Iinr2 = 5 x 2 x 2.3 kA = 16.3 kA
These tripping currents must be compared with the rated current of the current
sensors in order to select the accuracy limit factor:
^Iinr1 820 A ^Iinr2 16.3 kA
------------------ = -------------------------- = 3.9 < 6.7 and ------------------ = ---------------------- = 3.8 < 6.7
2I N 2 x 150 A 2I N 2 x 3 kA
The accuracy limit factor is, therefore, 20, with a rated burden of:
VACT Rw.iN2.
The following sensors are selected:
b for winding 1: 150 A/1 A, 5P20 where VACT1
b for winding 2: 3 kA/1 A, 5P20 where VACT2.
Setting the Percentage-based Curve and the Maximum Threshold
As this transformer does not feature a tap changer or an auxiliary winding, the
tripping threshold is, therefore, set to a minimum value (Ids = 30%) and the slope to
Id/It = 15%.
As the ratio between the closing current and the rated current is less than 8/2, the
self-adaptive harmonic restraint is selected. The second slope on the percentage-
based curve and the maximum threshold are not necessary and are not, therefore,
used.
Example 2
2.5 MVA, Dyn11, 20.8 kV/420 V transformer, the peak closing current is:
DE52178
The transformer features a tap changer with a tap range of 15% of the rated voltage
of winding 2.
Sensor selection
The rated current of the windings is:
S 2.5 MVA S 2.5 MVA
I N 1 = --------------------- = ------------------------ = 69 A and I N 2 = --------------------- = ----------------------- = 3.4 kA
3 V L L n1 320.8 kV 3 V L L n2 3420 V
Thanks to the tap changer, the current sensors can support an overload of 115%:
IN > 69 A x 1.15 = 79.4 A and I'N > 3.4 kA x 1.15 = 3.91 kA
The main currents of the CTs must also meet the following requirements:
S S S S
0.1 --------------------- y I N y 2.5 --------------------- and 0.1 --------------------- y I N y 2.5 ---------------------
3 V L L n1 3 V L L n1 3 V L L n2 3 V L L n2
So, for this transformer:
6.9 A IN 173 A and 340 A IN 8.5 kA
3
Taking these two restrictions into account, the values selected are those
standardized by the IEC:
In = 100 A and I'n = 4 kA
The tripping current is ^Iinr = 9,6 ^IN , so, for both winding 1 and winding 2:
^Iinr1 = 9.6 x 2 x 69 A = 937 A
^Iinr2 = 9.6 x 2 x 3.4 kA = 46.2 kA
These tripping currents must be compared with the rated current of the CTs in order
to select the accuracy limit factor:
^Iinr1 937 A ^Iinr2 46.2 kA
------------------ = -------------------------- = 6.6 < 6.7 and ------------------ = ---------------------- = 8.2 > 6.7
2I N 2 x 100 A 2I N 2 x 4 kA
The accuracy limit factor is, therefore, 20 for the sensors in winding 1
^Iinr2 46.2 kA
and equal to 3 ------------------ = 3 ---------------------- = 24.5 for winding 2.
2I N 2 x 4 kA
The closest standard value, 30, is selected.
The following sensors are selected:
b for winding 1: 100 A/1A, 5P20
b for winding 2: 4 kA/1A, 5P30.
Setting the Percentage-Based Curve and the Maximum Threshold
This transformer features a tap changer. The continuous differential current due to
the voltage variation of the tap changer is:
x
Idchanger = ------------ x 100%
1x
where x is the maximum variation of the tap changer. In this example, x = 0.15.
The differential current due to the change in the transformation ratio is:
0.15
Idchanger = --------------------- x 100% = 17.6%
1 0.15
Type 5P sensors with a maximum measurement error tolerance of 10% are used.
The measurement accuracy of the relay is 1% for Ids and Id/It.
The minimum setting is, therefore:
Ids = IdChanger + IdMeasure + IdRelay + margin.
Assuming a margin of approximately 5%, the minimum setting is, therefore:
Ids = 17.6 + 10 + 1 + 5 34%
Ids and the Id/It slope are set to 34%.
The ratio between the closing current and the rated current is 9.6. As this ratio is
greater than 8/2, the conventional harmonic restraint is selected.
The second slope on the percentage-based curve is set to 70%, starting at 6 IN1 in
order to ensure sufficient stability of the protection fault in the event of external faults.
The high set point is set to a value higher than that of the closing current with the
following margin:
^Ii N r
Idmax = 2 x ------------ = 2 x 9.6 In1 = 13.6 In1
^IN
The conventional harmonic restraint is set with:
b a second-harmonic set point equal to 20%, with cross-blocking
b a fifth-harmonic set point equal to 25%, without cross-blocking.
MT10911
b timer hold.
Is I
Definite time protection principle
IDMT Protection
The operation time depends on the protected value (phase current, ground fault
3 current, etc.) in accordance with standards IEC 60255-3, BS 142 and IEEE C-37112.
Operation is represented by a characteristic curve, e.g.:
b t = f(I) curve for the phase overcurrent function
b t = f(Ir) curve for the ground fault function.
The rest of the document is based on t = f(I); the reasoning may be extended to other
variables Ir, etc.
The curve is defined by:
b its type (standard inverse, very inverse, extremely inverse, etc.)
b current setting Is which corresponds to the vertical asymptote of the curve
b time delay T which corresponds to the operation time for I = 10 Is
These three settings are made in order of type, Is current, and time delay T.
Changing the time delay T setting by x% changes all of the operation times in the
curve by x%.
type 1
t
DE50666
type 1,2
1 1.2 10 20 I/Is
IDMT protection principle
The tripping time for I/Is values less than 1.2 depends on
the type of curve selected.
Name of Curve Type
Standard inverse time (SIT) 1.2
Very inverse time (VIT or LTI) 1.2
Extremely inverse time (EIT) 1.2
Ultra inverse time (UIT) 1.2
RI curve 1
IEC inverse time SIT / A 1
IEC very inverse time VIT or LTI / B 1
IEC extremely inverse time EIT / C 1
IEEE moderately inverse (IEC / D) 1
IEEE very inverse (IEC / E) 1
IEEE extremely inverse (IEC / F) 1
IAC inverse 1
IAC very inverse 1
IAC extremely inverse 1
b when the monitored value is more than 20 times the set point, the tripping time
is limited to the value corresponding to 20 times the set point.
b if the monitored value exceeds the measurement capacity of Sepam (40 IN
for the phase current channels, 20 INr for the residual current channels), the
tripping time is limited to the value corresponding to the largest measurable
value (40 IN or 20 INr).
RI curve
1 T
Equation: t d ( I ) = ----------------------------------------------------- ------------------
1 3.1706
0.339 0.236 ----
I
I s 3
IEEE Curves
Equation Curve Type Coefficient Values
A B p
Moderately inverse 0.010 0.023 0.02 0.241
Very inverse 3.922 0.098 2 0.138
Extremely inverse 5.64 0.0243 2 0.081
A T
t d ( I ) = ---------------------- + B ---
I p
---- 1
I
s
IAC Curves
Equation Curve Type Coefficient Values
A B C D E
Inverse 0.208 0.863 0.800 -0.418 0.195 0.297
Very inverse 0.090 0.795 0.100 -1.288 7.958 0.165
Extremely inverse 0.004 0.638 0.620 1.787 0.246 0.092
B D E T
t d ( I ) = A + ------------------- + ---------------------- + ---------------------- x -----
---I- C ---I- C 2 ---I- C 3
I I I
s s s
B 1
C 2
1
t ( G ) = ------------------------- x T
d ------- 1
G p
G
s
DE50754
(application menu), this curve may be used to solve all special cases involving
protection coordination or installation renovation.
The two end points define the curve asymptotes. There must be at least one point on
the horizontal coordinate 10 I/Is to serve as a reference point to set the function time
delay by curve shifting.
Theoretically, the Is current setting corresponds to the The time delay setting to be used so that the operation curve passes through the
maximum continuous current. It is generally the rated point k (Ik, tk) is:
current of the protected equipment (cable, transformer).
The time delay T corresponds to operation at 10 Is on ts
MT10215
the curve. This setting is determined by factoring the tk
constraints involved in discrimination with the upstream T = Ts10 ---------
tsk
and downstream protection devices.
tk k
The discrimination constraint leads to the definition of
point A on the operation curve (IA, tA), like the point that
1 Ik/Is 10 I/Is
Another practical method:
the table below gives the values of K = ts/ts10 as a function of I/Is.
In the column that corresponds to the type of time delay, read the value K = tsk/Ts10
on the line for Ik/Is.
The time delay setting to be used so that the operation curve
passes through point k (Ik, tk) is: T = tk/k.
Example
Data:
b type of time delay: standard inverse time (SIT)
b set point: Is
b a point k on the operation curve: k (3.5 Is; 4 s)
Question: What is the time delay T setting (operation time at 10 Is)?
Reading the table: SIT column, line I/Is = 3.5 therefore K = 1.858
Answer: The time delay setting is T = 4/1.858 = 2.15 s
Answer: The operation time for the current IA is t = 1.80 x 0.8 = 1.44 s.
tA
T
tsA
Ts10
3
1 IA/Is 10 I/Is
Table of K Values
I/Is SIT VIT, LTI EIT UIT RI IEEE MI IEEE VI IEEE EI IAC I IAC VI IAC EI
and IEC/A and IEC/B and IEC/C (IEC/D) (IEC/E) (IEC/F)
1.0 3.062 62.005 62.272 200.226
1.1 24.700 (1) 90.000 (1) 471.429 (1) 2.534 22.461 136.228 330.606 19.033 45.678 122.172
1.2 12.901 45.000 225.000 545.905 2.216 11.777 65.390 157.946 9.413 34.628 82.899
1.5 5.788 18.000 79.200 179.548 1.736 5.336 23.479 55.791 3.891 17.539 36.687
2.0 3.376 9.000 33.000 67.691 1.427 3.152 10.199 23.421 2.524 7.932 16.178
2.5 2.548 6.000 18.857 35.490 1.290 2.402 6.133 13.512 2.056 4.676 9.566
3.0 2.121 4.500 12.375 21.608 1.212 2.016 4.270 8.970 1.792 3.249 6.541
3.5 1.858 3.600 8.800 14.382 1.161 1.777 3.242 6.465 1.617 2.509 4.872
4.0 1.676 3.000 6.600 10.169 1.126 1.613 2.610 4.924 1.491 2.076 3.839
4.5 1.543 2.571 5.143 7.513 1.101 1.492 2.191 3.903 1.396 1.800 3.146
5.0 1.441 2.250 4.125 5.742 1.081 1.399 1.898 3.190 1.321 1.610 2.653
5.5 1.359 2.000 3.385 4.507 1.065 1.325 1.686 2.671 1.261 1.473 2.288
6.0 1.292 1.800 2.829 3.616 1.053 1.264 1.526 2.281 1.211 1.370 2.007
6.5 1.236 1.636 2.400 2.954 1.042 1.213 1.402 1.981 1.170 1.289 1.786
7.0 1.188 1.500 2.063 2.450 1.033 1.170 1.305 1.744 1.135 1.224 1.607
7.5 1.146 1.385 1.792 2.060 1.026 1.132 1.228 1.555 1.105 1.171 1.460
8.0 1.110 1.286 1.571 1.751 1.019 1.099 1.164 1.400 1.078 1.126 1.337
8.5 1.078 1.200 1.390 1.504 1.013 1.070 1.112 1.273 1.055 1.087 1.233
9.0 1.049 1.125 1.238 1.303 1.008 1.044 1.068 1.166 1.035 1.054 1.144
9.5 1.023 1.059 1.109 1.137 1.004 1.021 1.031 1.077 1.016 1.026 1.067
10.0 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000
10.5 0.979 0.947 0.906 0.885 0.996 0.981 0.973 0.934 0.985 0.977 0.941
11.0 0.959 0.900 0.825 0.787 0.993 0.963 0.950 0.877 0.972 0.957 0.888
11.5 0.941 0.857 0.754 0.704 0.990 0.947 0.929 0.828 0.960 0.939 0.841
12.0 0.925 0.818 0.692 0.633 0.988 0.932 0.912 0.784 0.949 0.922 0.799
12.5 0.910 0.783 0.638 0.572 0.985 0.918 0.896 0.746 0.938 0.907 0.761
13.0 0.895 0.750 0.589 0.518 0.983 0.905 0.882 0.712 0.929 0.893 0.727
13.5 0.882 0.720 0.546 0.471 0.981 0.893 0.870 0.682 0.920 0.880 0.695
14.0 0.870 0.692 0.508 0.430 0.979 0.882 0.858 0.655 0.912 0.868 0.667
14.5 0.858 0.667 0.473 0.394 0.977 0.871 0.849 0.631 0.905 0.857 0.641
15.0 0.847 0.643 0.442 0.362 0.976 0.861 0.840 0.609 0.898 0.846 0.616
15.5 0.836 0.621 0.414 0.334 0.974 0.852 0.831 0.589 0.891 0.837 0.594
16.0 0.827 0.600 0.388 0.308 0.973 0.843 0.824 0.571 0.885 0.828 0.573
16.5 0.817 0.581 0.365 0.285 0.971 0.834 0.817 0.555 0.879 0.819 0.554
17.0 0.808 0.563 0.344 0.265 0.970 0.826 0.811 0.540 0.874 0.811 0.536
17.5 0.800 0.545 0.324 0.246 0.969 0.819 0.806 0.527 0.869 0.804 0.519
18.0 0.792 0.529 0.307 0.229 0.968 0.812 0.801 0.514 0.864 0.797 0.504
18.5 0.784 0.514 0.290 0.214 0.967 0.805 0.796 0.503 0.860 0.790 0.489
19.0 0.777 0.500 0.275 0.200 0.966 0.798 0.792 0.492 0.855 0.784 0.475
19.5 0.770 0.486 0.261 0.188 0.965 0.792 0.788 0.482 0.851 0.778 0.463
20.0 0.763 0.474 0.248 0.176 0.964 0.786 0.784 0.473 0.848 0.772 0.450
(1) Values suitable only for IEC A, B and C curves.
Standard Inverse Time (SIT) Curve Very Inverse Time (VIT) or LTI Curve
DE50869a
1000 10000
1000
100
OPERATE TIME [S]
RI Curve
RI
DE50869b
100
12.5
10
OPERATE TIME [S]
5.0
2.5
1.2
1
0.8
0.4
0.2
0.1 0.1
0.01
1 10 100
I / Is
Extremely Inverse Time (EIT) Curve Ultra Inverse Time (UIT) Curve
DE50870a
10000
10000
1000
1000
100
OPERATE TIME [S]
100
TIME(S)
10 10 3
12.5
12.5
1 5.0
1 5.0
2.5
2.5
1.2 1.2
0.8 1.0
0.4 0.8
0.1 0.1 0.4
0.2
0.2
0.1
0.1
0.01
0.01
1 10 100 1 10 100
I / Is I / Is
MT10206a
1000 10000
1000
100
100
10 12.5
10 12.5
5.0
2.5 5.0
3 1
2.0
1.2
0.8
1
2.5
1.2
1.0
0.8
0.4 0.4
0.2
0.2 0.1 0.1
0.1 0.1
0.01
1 10 100
0.01 I / Is
1 10 100
I / Is
IEEE Curves
IEEE EI [IEC-F]
MT10206b
10000
1000
100
OPERATE TIME [S]
10
12.5
5.0
1 2.5
1.2
0.8
0.4
0.1 0.2
0.1
0.01
1 10 100
I / Is
IAC-SIT IAC-VIT
DE50869
DE50870
1000
1000
100
100
10 12.5 12.5
10
5.0 5.0
2.5 2.5
1 1.2
0.8
1 1.2 3
0.8
0.4 0.4
0.2 0.2
0.1 0.1 0.1 0.1
0.01 0.01
1 10 100 1 10 100
I / Is I / Is
IAC Curves
IAC-EIT
MT10206
MT10207
10000
1000
OPERATE TIME [S]
100
10
12.5
5.0
1 2.5
1.2
0.8
0.4
0.1 0.2
0.1
0.01
1 10 100
I / Is
Description 182
Definition of Symbols 183
Logic Input/Output Assignment 184
Switchgear Control 188
Capacitor Bank Switchgear Control 199
Latching/Acknowledgement 207
TC/Switchgear Position Discrepancy 208
Disturbance-Recording Trigger 209
Switching Groups of Settings 210
Zone Selective Interlocking 211
Load Shedding 222
Motor Auto-Restart 223
Generator Shutdown & Tripping 225
Automatic Transfer 229
Automatic Transfer "Main-Main" 231
Automatic Transfer "Main-Tie-Main" 239 4
Local Indication 248
Local Control 251
Control Matrix 254
Logic Equations 256
Customized Functions Using Logipam 260
Sepam performs all the control and monitoring functions required for electrical
network operation. The main control and monitoring functions are predefined and fit
the most frequent cases of use. They are ready to use and are implemented by
simple parameter setting after the necessary logic inputs / outputs are assigned.
The predefined control and monitoring functions can be adapted for particular needs
using the SFT2841 software, which offers the following customization options:
b logic equation editor, to adapt and complete the predefined control and
monitoring functions
b creation of personalized messages for local annunciation
b creation of personalized mimic diagrams corresponding to the controlled
devices
b customization of the control matrix by changing the assignment of output
relays, LEDs and annunciation messages
With the Logipam option, Sepam provides the most varied control and monitoring
functions, programmed using the SFT2885 programming software that implements
the Logipam ladder language.
Operating Principle
The processing of each control and monitoring function may be broken down into
three phases:
1 acquisition of input data:
b results of protection function processing
b external logic data, connected to the logic inputs of an optional MES120 input
4 / output module
b local control commands transmitted by the mimic-based UMI
b remote control commands (TC) received via the communication link
2 actual processing of the control and monitoring function
3 utilization of the processing results:
b activation of output relays to control a device
b information sent to the facility manager:
v by message and/or LED on the Sepam display and SFT2841 software
v by remote indication (TS) via the communication link
v by real-time indications on device status on the animated mimic diagram.
The five outputs included in the Sepam Series 80 base unit may be extended by
adding one, two, or three MES120 modules with 14 logic inputs and 6 output relays
each.
After the number of MES120 modules needed for an application is set, the logic
inputs are assigned to functions. The functions are chosen from a list that covers the
whole range of possible uses. The functions are adapted to meet needs within the
limits of the logic inputs available. The inputs may also be inverted for undervoltage
type operation.
A default input / output assignment is proposed for the most frequent uses.
This page gives the meaning of the symbols Pulse Mode Operation
used in the block diagrams illustrating the The "on" pulse: used to create a short-duration pulse (200 ms) each time a signal
different control and monitoring functions in appears
this chapter.
DE50681
Logic Functions
"OR"
DE50675
Equation: s = x or y or z.
b "off" pulse: used to create a short-duration pulse (200 ms)
"AND" each time a signal disappears.
DE50676
DE50682
exclusive OR "XOR"
4
DE50677
Equation: s = x (s = 1 if x = 0).
Delay Timers
There are two types of delay timers:
b "on" delay timer: used to delay the appearance
of a signal by a time T
DE50679
Equation: B = S + R x B.
Inputs and outputs may be assigned to predefined control and monitoring functions
using the SFT2841 software, according to the uses listed in the table below. The
control logic of each input may be inverted for undervoltage type operation.
All logic inputs, whether assigned to predefined functions or not, can be used for the
customization functions according to specific application needs:
b in the control matrix (SFT2841 software), to connect an input to a logic output,
a LED on the front of Sepam or a message for local indication on the display
b in the logic equation editor (SFT2841 software), as logic equation variables
b in Logipam (SFT2885 software) as input variables for the program in ladder
language
4 Genset shutdown
De-excitation
b
b
b
b
Free
Free
Load shedding b b Free
AT, closing of NO circuit breaker b b b b b b b b b b Free
AT, closing of tie breaker b b b b b b b b b b Free
AT, opening of tie breaker b b b b b b b b b b Free
Tripping of capacitor step (1 to 4) b Free
Tripping of capacitor step (1 to 4) b Free
Note: The logic outputs assigned by default may be freely reassigned.
The table below lists the logic input assignment obtained with the SFT2841
configuration software by clicking on the "standard assignment" button.
For sync-check to operate, one of the Close enable logic outputs of an MCS025
Processing Internal Switchgear Control remote module must be connected to a Sepam logic input assigned to the Close
Commands enable function.
4 The Switchgear control function processes all breaking
device closing and tripping conditions, based on:
b protection functions (configured to trip the
If it is necessary to close the circuit breaker without taking into account the
synchronization conditions, this may be done by a logic equation or by Logipam via
breaking device) the V_CLOSE_NOCTRL input.
b breaking device status data
b remote control via the communication link
b local control commands by logic input or mimic- Controlling Logic Outputs
based UMI Logic commands from the Switchgear control function are used to control the
b internal control commands created by logic Sepam logic outputs that control breaking device opening and closing.
equation or Logipam
b specific predefined control functions for each Logic output control is set up to match the device to be controlled, i.e. a circuit
application: breaker or contactor.
v recloser
v genset shutdown, de-excitation Controlling Capacitor Banks
v load shedding The Sepam C86 Switchgear control function can control the breaking device and
v sync-check 1 to 4 capacitor step switches.
v automatic transfer
v capacitor step control. This particular function is described separately.
The function also blocks breaking device closing,
according to the operating conditions.
Logic
Outputs
Control
(Circuit
breaker or
magnetically
held
contactor)
Sync-
Check 4
Sync-
Check
The closing command is given if the close enable is received before the close
request delay runs out. When this is the case, the message "SYNC. OK" is displayed.
If the close enable is not received, the message "SYNC. FAILURE" is displayed.
When possible and if the MCS025 remote module is connected by the CCA785 cord
to the Sepam to which the close request has been made, an additional message
indicates the type of synchronization failure:
b "SYNC. FAILED dU" for too high a voltage difference
b "SYNC. FAILED DF" for too high a frequency difference
b "SYNC. FAILED dPhi" for too high a phase difference.
An additional delay is used to confirm the close enable to guarantee that the closing
conditions last long enough.
Block Diagram
4
DE52273
Parameter Setting
The Switchgear control function is set up and adapted to match the type of breaking
device to be controlled using the SFT2841 software.
b
4 the Trip command is always associated with output O1.
If output O1 is set up for pulse type operation, the pulse command duration
PE50455
may be set up
b the optional Close block and Close commands may be assigned to any logic
output.
193
SEPAM SERIES 80 - BREAKER AC 3-LINE (Typical)
a
Breaker AC 3-Line (Typical)
b
c
Switchgear Control
Contactor Diagrams
63230-216-230B1
3VTs
2VTs
Typical Breaker &
11 - Sepam 11 - Sepam
PowerLogic
SER 80 PowerLogic SER 80
ALL CM or PM ALL CM or PM
Test Test
Sw Sw
E1 E1
52
E2 E2
E2 E4
E4 E5
E7
Test 11 - Sepam PowerLogic Test
Sw SER 80 CM or PM Sw E8
S horting TB
B104 B101
19 20
3 CTs B105 B102
63230-216-230-B1.book Page 193 Monday, August 6, 2007 10:35 AM
xxxx/5A
Control and Monitoring
B106 B103
Detect
xxxx/5A Relay
Sepam Series 80
a b c
63230-216-230-B1.book Page 194 Monday, August 6, 2007 10:35 AM
Sepam
CIRCUIT BREAKER TRIP CIRCUIT CIRCUIT BREAKER CLOSE CIRCUIT
Series 80 FU
USING SEPAM SERIES 80
FU
USING SEPAM SERIES 80
Relay
GND
A1 11
A4 11
01
H101 11
I101
H104 11
I102
52CS GIL RIL
A10 11
03 52CS
EXT.
CONT
{ TO
OTHER
CLOSE
pwr A5 H102 H105 T Close C INPUT
sup A11 (if used) INPUTS
A2
A7 11
02 Sepam
{
Close Series 80
A8 Inhibit
To other Relay
(if used)
Received (ZSI)
trip inputs
(If Used)
86
52 52 (if
A B used)
Note: jumper 1
1 preferred, Sepam
52 2 H107
52 11 Series 80
TC jumper 2
CC H108 I103 Relay
alternate.
4 FU FU
02
{
Close Series 80
63230-216-230-B1.book Page 195 Monday, August 6, 2007 10:35 AM
To other A8 Inhibit
48VDC Relay
trip inputs (if used)
(If Used)
52 86
Received (ZSI)
52 52 A (if
Block Fast Trip
A B used)
Note: jumper 1
1 preferred, Sepam
52 2 jumper 2 52 H107
11 Series 80
TC alternate. CC H108 I103 Relay
Y
xxx Vac Control Voltage
H134 A13
Typical Breaker &
A17 11 A19 11 11 11
Sepam
63230-216-230B1
05 05 O102 04
Contactor Diagrams
Series 80
Switchgear Conrtol
195
4
63230-216-230-B1.book Page 196 Monday, August 6, 2007 10:35 AM
AC MOTOR BUS
89
AC MOTOR BUS
(2)VT's
FU
89 FU
(2)VT's
FU
FU E1
E2 42M
E4 MAIN
E1
E2
E4
{
42M
42R
RUN
AUTO
4
}
(3) 1 TRANSFORMER
CT 5
B1
50/65/80%
2
4
}
6
3 (3) 1
E14 PHASE 1 PHASE 2 CT 5
2 B1
(1)ZSCT
E15 6
4
3
E14
M
{ 42S
START
(1)ZSCT
E15
M
4
}
(3) 1
CT 5
2 B2
4
}
6
3 (3) 1
CT 5
2 B2
6
3
RE 5 1CR
5E
REM LOC
STOP EMERG
STOP STOP
42S 42M RR
TB
5 43 43
LOC 11M
L R
STOP 02
43 43 5 43
L
R L
O LOC
TB 11M 43
E O
C
R R L
M F STOP 011
F RE1
TB 1 PLC
1CR LOC START REM LOC
1 RE1 1CR 1CR
LOC START /STOP START START
TO REMOTE
START START
CPT TB
TB
11M REM
11M 1CR 02 STOP
02 INHIBIT START
INHIBIT START 11M
01 11M
11M 11M MR
01 014
01 42R 42S
PROT STOP STOP MR RR SR 1SR RUN CURRENT TDO
TDO
42 42 1CR 42 42 42 1CR 1SR MR RR SR
1CR
M M M R S TDPU TDPU
{
{
{
Full Voltage Non-Reversing (FVNR) FVNR (Var1) Reduced Voltage Autotransformer (RVAT) Start Controls
Start Controls (Typical)
with (2)
Remote Contacts
with (1)
Remote Contact 4
Timing Diagram
MAIN CONT
RUN CURR
ON
INIT. START 011
OFF
SR
START
CONT 42S
MR
MAIN
CONT 42M
ST-RUN
CURR
TRANSIT
LEVEL 014
RR
RUN
CONT 42R
INCOMPL
SEQ ISR
Characteristics
Settings
Switchgear Control
Setting range On / Off
Type of Device
Setting range Circuit breaker / Contactor
Tripping Pulse Duration (Output O1)
Setting range 200 ms to 300 s
Accuracy (1) 2% or from -10 ms to +25 ms
Resolution 10 ms or 1 digit
Closing with Sync-Check
Setting range On / Off
Close Request Time Delay Tdf
Setting range 0 to 300 s
Accuracy (1) 2% or from -10 ms to +25 ms
Resolution 10 ms or 1 digit
Sync Confirmation Time Delay Tcs
Setting range 0 to 300 s
Accuracy (1) 2% or from -10 ms to +25 ms
Resolution 10 ms or 1 digit
Inputs
Designation Syntax Equations Logipam
Tripping, opening V_TRIPCB b b
4 Block closing
Closing
V_BLOCKCLOSE
V_CLOSECB
b
b
b
b
Closing without sync-check V_CLOSE_NOCTRL b b
Outputs
Designation Syntax Equations Logipam Matrix
Switchgear control on V_SWCTRL_ON b
Tripping, opening V_TRIPPED b b b
Block closing V_BLOCK_CLOSE b b b
Closing V_CLOSED b b b
Contactor control V_CONTACTOR b b
Sync-check on V_SYNC_ON b b
Sync-check close request in V_SYNC_INPROC b b
process
Sync-check close request stop V_SYNC_STOP b b
Sync-check close request V_SYNC_OK b b
successful
Sync-check close request failure V_NOSYNC b b
Sync-check close request failure - V_NOSYNC_DU b b
Voltage difference too high
Sync-check close request failure - V_NOSYNC_DF b b
Frequency difference too high
Sync-check close request failure - V_NOSYNC_DPHI b b
Phase difference too high
(1) Under reference conditions (IEC 60255-6).
Logic output control is set up to match the type of device to be controlled, like a circuit
breaker or capacitor step switch.
Anti-Pumping Function
To prevent simultaneous breaking device open and close commands and to give
priority to open commands, breaker device close commands are of the pulse type
Manual Control
When the "Manual capacitor step control" logic input is on, each step may be opened
and closed manually:
b locally by specific logic inputs (one open input and one close input per step)
b remotely by remote control.
Latched trip commands block capacitor step closing until the commands are reset
14 . Open commands must be at least as long as the duration of open and close
control pulses.
Capacitor step switches only close after the capacitor step discharge time delay has
run out and after the circuit breaker has closed, if there is no protection fault or
blocking.
In the event of a capacitor step switch matching fault, the switch close command is
blocked.
Block Diagram
DE52277
Characteristics
Settings
Switchgear Control
Setting range On / Off
Device Type
Setting range Circuit breaker / Contactor
Tripping Pulse Duration (Output O1)
Setting range 200 ms to 300 s
Accuracy (1) 2% or from 10 ms to +25 ms
Resolution 10 ms or 1 digit
Control of Capacitor Banks
Setting range On / Off
Staggered Capacitor Step Opening Time Delay Techx (1 delay per step)
Setting range 0 to 300 s
Accuracy (1) 2% or from 10 ms to +25 ms
Resolution 10 ms or 1 digit
Capacitor Step Discharge Time Delay Tdx (1 delay per step)
Setting range 0 to 300 s
Accuracy (1) 2% or from 10 ms to +25 ms
Resolution 10 ms or 1 digit
Capacitor Step Open and Close Control Pulse Duration Timp
Setting range 0 to 300 s
Accuracy (1) 2% or from 10 ms to +25 ms
4 Resolution
Inputs
10 ms or 1 digit
Operation
The tripping outputs of all protection functions and logic inputs can be latched
individually.
Logic outputs cannot be latched. Logic outputs set up as pulse-type outputs maintain
pulse-type operation even when they are linked to latched data. Latched data is
saved in the event of an auxiliary power loss
All latched data are acknowledged together, at the same time. Acknowledgement is
done:
b locally on the UMI using the key
b or remotely via a logic input, the SFT2841 software or via the communication
link
b or by logic equation or Logipam.
The remote indication TS5 remains present after latching operations until
acknowledgement takes place. The Latching/acknowledgement function associated
with the Switchgear control function can be used to perform the ANSI 86 Lockout
relay function.
Block Diagram
DE52251
Characteristics
Inputs
Designation Syntax Equations Logipam
Blocking UMI Reset key V_BLOCK_RESET_LOCAL b b
Acknowledgement by logic V_RESET b b
equation or Logipam
Outputs
Designation Syntax Equations Logipam Matrix
Reset requested V_RESET_ORD b
Acknowledgement by UMI V_KEY_RESET b
Reset key
Operation
This function detects any discrepancy between the last remote control command
received and the actual position of the circuit breaker or contactor.
The information is accessible in the matrix and via the remote indication TS3.
Block Diagram
DE51637
Characteristics
Outputs
Designation Syntax Equations Logipam Matrix
TC/ switchgear position V_TC/CBDISCREP b
discrepancy
Operation
Recording analog and logic signals can be triggered by different events, according to
control matrix parameter setting or by manual action:
b triggering by the grouping of all pick-up signals of the protection functions in
service
b triggering by the delayed outputs of selected protection functions
b triggering by selected logic inputs
b triggering by selected outputs Vx (logic equations)
b manual triggering by a remote control command (TC20)
b manual triggering via the SFT2841 software tool
b manual triggering by Logipam
Block Diagram
DE52252
{
{
{
{
Characteristics
Inputs
Designation Syntax Equations Logipam
Blocks disturbance recording V_OPG_BLOCK b
function
Validates disturbance recording V_OPG_VALID b
function
Manual trigger of disturbance V_OPG_MANUAL b
recording function
Outputs
Designation Syntax Equations Logipam Matrix
Disturbance recording function V_OPG_TRIGGED b
triggered
Disturbance recording function V_OPG_BLOCKED b b
blocked
Disturbance recording on V_OPG_ON b
Operation
There are two groups of settings, A and B, for the phase overcurrent, ground fault,
directional phase overcurrent and directional ground fault protection functions.
Switching from one group to another makes it possible to adapt the protection
characteristics to suit the electrical environment of the application (change of
grounding system, changeover to local power generation). Switching settings is
global and applies to all the units of the protection functions mentioned above.
Block Diagram
DE50807
Group A forced
Choice by logic input Group A active
Logic input for A/B switching V_GROUPA
Group b forced
4 Choice by logic input
Logic input for A/B switching
Group B active
V_GROUPB
Characteristics
Outputs
Designation Syntax Equations Logipam Matrix
Group of settings A active V_GROUPA b
Group of settings B active V_GROUPB b
Operation
This function significantly reduces the tripping time of the circuit breakers closest to
DE50623
N.O.
the source. It can be used for zone selective interlocking (ZSI) in closed ring
networks. It applies to the phase overcurrent 50/51, directional phase overcurrent
67, ground fault 50N/51N and directional ground fault 67N protection functions,
definite time and IDMT.
N.O.
Sepam Series 80 ZSI logic includes two logic groups. Each group includes:
b logic thresholds: protection units that send blocking signals (BSIG) and may
N.O. N.O. be prevented from tripping by the reception of blocking signals.
b time-based thresholds: protection units that may not be prevented from
tripping by blocking signals and do not send blocking signals. They are used
N.O. N.O. as backup for the logic thresholds.
N.O. N.O.
When a fault occurs:
M M b the logic thresholds detecting the fault send blocking signals upstream
M
b the logic thresholds detecting the fault send a tripping command if they are not
N.O.
N.O. blocked by blocking signals
M b the time-based (backup) thresholds detecting the fault send a tripping
command
Example: radial distribution with use of time-based The logic and time-based threshold assignments of the protection units depend on
discrimination (T: protection setting time. As an approximation
for definite time curves, this is assumed to be equal to the
the type of application and the parameter setting of the logic inputs/outputs.
protection tripping time). The first logic group is active if one of the following two conditions is met:
b blocking reception 1 is assigned to a logic input Ixxx, except for motors which
The upstream protection units are typically delayed by 0.3 s to do not have this input.
give the downstream protection units time to trip. When there b blocking send 1 is assigned to an output Oxxx. (O102 by default).
are many levels of discrimination, the fault clearing time at the
source is long.
When the second logic group is present in the application, it is active under one of
the following two conditions:
4
In this example, if the fault clearing time for the protection unit b blocking reception 2 is assigned to a logic input Ixxx
furthest downstream is Xs = 0.2 s, the fault clearing time at the b blocking send 2 is assigned to an output Oxxx (O103 by default).
source is T = Xs + 0.9 s = 1.1 s
The SFT 2841 software indicates the type of threshold, logic or time-based,
according to the input/output parameter setting.
DE50809
DE50810
N.O. N.O.
N.O. N.O.
N.O.
Send BSIG1
output to
M M M other level
N.O. N.O. n Sepams
Example: radial distribution with use of zone selective Assigning protection devices to the two ZSI groups is fixed and cannot be modified.
interlocking When ZSI is used, it is important to ensure that the measurement origin and logic
(T: protection setting time. As an approximation for definite group to which the unit is assigned are in accordance.
time curves, this is assumed to be equal to the protection
tripping time).
When a fault appears, the protection units that detect it block By default, the same logic group has the same measurement origin. When several
the upstream protection units. The protection unit furthest origins are possible, the main channels Ia, Ib, Ic and Ir are assigned by default to the
downstream trips since it is not blocked by another protection first group and the additional channels I'a, I'b, I'c, I'r to the second.
unit. The delays are to be set in accordance with the device to
be protected.
In this example, if the fault clearing time for the protection
device furthest downstream is Xs = 0.2 s, the fault clearing time
at the source is T = Xs - 0.1 s = 0.1 s.
ZSI TIME SAVING VS TIME-BASED COORDINATION The duration of blocking signals lasts as long as it takes to clear the fault. If Sepam
1000 issues a tripping command, the blocking signals are interrupted after a time delay
that takes into account the breaking device operating time and the protection unit
reset time. This system guarantees safety in downgraded operating situations (faulty
100
wiring or switchgear).
10
carry interlocks between breaker/relay functions.
1
R6 - Relay 6
R3 - Relay 3
R2 - Relay 2
R4 - Relay 4
0.1 R1 - Relay 1
R5 - Relay 5
0.01
10 100 1000 10000 100000
Current ( amperes )
Threshold Assignment
Type of Unit Number
Protection Time-Based Send Logic Reception Logic
Group 1 Group 2 Group 1 Group 2
50/51 3, 4, 5, 6, 7, 8 1, 2 - 1, 2 -
50N/51N 3, 4, 5, 6, 7, 8 1, 2 - 1, 2 -
67N 2 1 - 1 -
(1) According to application.
Characteristics
Settings
Activity
Setting range On / Off
Outputs
Designation Syntax Equations Logipam Matrix
Zone selective Interlocking trip V_LOGDSC_TRIP b b b (1)
Blocking send 1 V_LOGDSC_BL1 b b b
Zone selective Interlocking on V_LOGDSC_ON b
(1) Only if switchgear control is not in service.
Block Diagram
Logic Thresholds
4
DE51619
Overcurrent
unit 1 pickup
unit 2 pickup
Ground Fault
unit 1 pickup
unit 2 pickup
Overcurrent
Ground Fault
Zone sequence
interlocking trip
(V_LOGDSC_TRIP)
Overcurrent
Ground Fault
(1) By default.
(2) According to application.
Threshold Assignment
Type of Unit Number
Protection Time-Based Send Logic Reception Logic
Group 1 Group 2 Group 1 Group 2
50/51 3, 4, 5, 6, 7, 8 1, 2 - - -
50N/51N 3, 4, 5, 6, 7, 8 1, 2 - - -
67N 2 1 - - -
Characteristics
Settings
Activity
Setting range On / Off
Outputs
Designation Syntax Equations Logipam Matrix
Zone selective Interlocking trip V_LOGDSC_TRIP b b (1)
Blocking send 1 V_LOGDSC_BL1 b b
Zone selective Interlocking on V_LOGDSC_ON b
(1) Only if switchgear control is not in service.
Block Diagram
Logic Thresholds
DE51620
4 Overcurrent
unit 1 pickup
unit 2 pickup
Ground Fault
unit 1 pickup
unit 2 pickup
Overcurrent
Ground Fault
Overcurrent
Zone sequence
interlocking trip
Ground Fault (V_LOGDSC_TRIP)
Block Diagram
DE52318
Overcurrent
unit 1 pickup
unit 2 pickup
Ground Fault
unit 1 pickup
unit 2 pickup
unit 5 pickup
unit 6 pickup
Ground Fault
unit 5 pickup
unit 6 pickup
4
Blocking
reception
1 and 2
Zone sequence
interlocking trip
(V_LOGDSC_TRIP)
(1) By default.
(2) According to application.
Threshold Assignment
Type of Unit Number
Protection Time-Based Send Logic Reception Logic
Group 1 Group 2 Group 1 Group 2
50/51 3, 4, 7, 8 1, 2 5, 6 1, 2 5, 6
50N/51N 3, 4, 7, 8 1, 2 5, 6 1, 2 5, 6
67 (1) - 1 2 1 2
67N (1) - 1 2 1 2
(1) According to application.
Characteristics
Settings
Activity
Setting range On / Off
Outputs
Designation Syntax Equations Logipam Matrix
Zone selective Interlocking trip V_LOGDSC_TRIP b b (1)
Blocking send 1 V_LOGDSC_BL1 b b
Blocking send 2 V_LOGDSC_BL2 b b
Zone selective Interlocking on V_LOGDSC_ON b
(1) Only if switchgear control is not in service.
When a fault occurs in a radial network, the fault current flows through the circuit
between the source and the location of the fault: The protection units upstream from
the fault are triggered. The protection units downstream from the fault are not
triggered. Only the first protection unit upstream from the fault should trip.
Example of Setting
A 20 kV installation, supplied by a transformer, comprises the main bus which in turn
supply a feeder to a motor substation and a long feeder to a distant MV/LV
transformer. The installation is grounded via a resistor at the incoming transformer
neutral point, which limits the current to about 10 Amps.
DE50814
Group 1
50/51
67N
T = 0.4 s
Based on a network coordination study, the installation relay settings are as follows:
b main: Sepam T81 (relay A)
v bus fault thresholds
50/51, 50N/51N: T =0.1 s (DT)
Zone selective Interlocking group 1:
- blocked by relays B and D
- blocking send 1 to high voltage relays
v backup thresholds
50/51, 50N/51N: T = 0.7 s (DT)
Time-based thresholds
b feeder to motor substation: Sepam S80 (relay B)
v bus fault thresholds
50/51, 50N/51N: T = 0.1 s (DT)
Zone selective Interlocking group 1:
- blocked by relays C1 and C2
- blocking send 1 to relay A
v backup thresholds
50/51, 50N/51N: T = 0.4 s (DT)
Time-based thresholds
b motor feeders:
b motor 1: Sepam M81 (relay C1)
v motor fault thresholds
50/51, 50N/51N: T = 0.1 s (DT)
Zone selective Interlocking group 1:
The logic input and output settings for all the relays concerned are:
b blocking reception 1 on I103
b blocking send 1 on O102.
Substations supplied by two (or more) parallel mains may be protected using
Sepam S82, T82, or G82, by a combination of directional phase (67) and ground
fault (67N) protection functions, with the zone selective interlocking function.
Main 1 Main 2
DE50815
To avoid both mains tripping when a fault occurs upstream from one main, the main
protection devices must operate as follows:
b protection function 67 of the faulty main detects the fault current in the "line"
direction, the protection tripping direction:
4
v sends a blocking signal to block the phase overcurrent protection functions
(50/51) of both mains
v and initiates tripping of the main circuit breaker
b protection function 67 of the fault-free main is insensitive to fault current in the
"bus" direction.
Example of Setting
b logic input / output assignment:
v I104: blocking reception 2 - Do not assign any inputs to blocking
reception 1
v O102: blocking send 1
b protection function 67 unit 1: tripping direction = line
v instantaneous output: blocking send 1
v delayed output: not blocked (no input assigned to blocking signal 1), circuit
breaker tripping on faults upstream from main
b protection function 50/51, unit 5:
v delayed output:
- blocked by protection 67, unit 1 if there is a fault upstream from the
main
- not blocked for bus faults
- blocked for feeder faults
b protection function 50/51, unit 3 as backup.
Closed ring network protection may be provided by Sepam S82 or T82. This
includes the following functions:
b two units of directional phase (67) and ground fault (67N) protection functions:
v one unit to detect faults in the "line" direction
v one unit to detect faults in the "bus" direction
b use of two discrimination groups:
v sending two blocking signals according to the detected fault direction
v receiving two blocking signals to block the directional protection relays
according to the detection direction.
DE50816
With the combination of directional protection functions and the zone selective
interlocking function, the faulty section may be isolated with a minimal delay by
tripping of the circuit breakers on either side of the fault.
Blocking signals are initiated by both protection functions 67 and 67N. Priority is
given to protection function 67: when protection functions 67 and 67N detect faults
in opposite directions at the same time, the blocking signal sent is determined by the
direction of the fault detected by protection function 67.
The instantaneous output of protection functions 67 and 67N, activated at 80% of the
Is threshold, is used to send blocking signals. This avoids uncertainty when the fault
current is close to the Is threshold.
Example:
Case of a closed ring with two substations, each of which comprises two Sepam
S82 relays, marked R11, R12 and R21, R22.
DE50817
Starting at one end of the ring, the detection direction of units 1 and 2 of the
directional protection functions should be alternated between line and bus.
Operation
The purpose of load shedding is to reduce the load on the electrical network in order
to keep the voltage within an acceptable range.
Load shedding may be triggered by:
b a command from outside Sepam in the presence of a logic input assigned
for the reception of load shedding commands. Commands can be delayed
b a voltage dip detected by the delayed output of Sepam 27D protection unit
1 (typical setting 40% VLLN).
The load shedding command is maintained as long as one of the following three
conditions is present:
b external command via logic input
b positive sequence voltage detected by 27D unit 1 less than load shedding
voltage threshold
b insufficient positive sequence voltage detected by the delayed 27D unit 2 for a
restart command to be given . The time delay for the detection of correct
voltage recovery must be shorter than the load shedding delay (27D unit 1) in
order for the load shedding command to be maintained correctly. This unit is
also used by the restart function.
4 The function may be validated by the switchgear closed and not racked out
conditions.
Block Diagram
DE51607
Characteristics
Settings
Activity
Setting range On / Off
Delay Before Load Shedding
Setting range 0 to 300 s
Accuracy (1) 2% or from 10 ms to +25 ms
Resolution 10 ms or 1 digit
Outputs
Designation Syntax Equations Logipam Matrix
Load shedding command V_LOADSH_ORD b b
Load shedding on V_LOADSH_ON b
(1) Under reference conditions (IEC 60255-6).
Operation
This function enables motors to be automatically restarted after a shutdown caused
by load shedding. It allows staggered restarting of process motors, as long as the
voltage dip that caused load shedding was brief.
When tripping occurs due to a dip in the network supply voltage detected by 27D
protection unit 1, two outcomes are possible:
b the voltage dip lasts for a period longer than the maximum voltage dip duration:
tripping is final. External action is required for restart (see example 2).
b the voltage dip lasts for a period shorter than the maximum dip duration: a
restart command is given. Delayed restart allows motor restart commands to
be staggered to avoid network overload (see example 3).
Enabling restart is detected after the delayed output of protection 27D unit 2 drops
out. This threshold allows the return of voltage to be detected independently with
respect to the load shedding threshold. The typical setting is 50% VLLN.
Block Diagram
DE51608
Characteristics
Settings
Activity
Setting range On / Off
Maximum Voltage Dip Duration
Setting range 0 to 300 s
Accuracy (1) 2% or from 10 ms to +25 ms
Resolution 10 ms or 1 digit
Restart Delay
Setting range 0 to 300 s
Accuracy (1) 2% or from 10 ms to +25 ms
Resolution 10 ms or 1 digit
Outputs
Designation Syntax Equations Logipam Matrix
Restart command V_RESTARTING b
Restart on V_RESTART_ON b
(1) Under reference conditions (IEC 60255-6).
pickup
pickup
pickup
pickup
DE51609
b mechanical shutdown by shutting down the
prime mover
b electrical shutdown by tripping the generator.
DE51610
fault when the generator is disconnected from the
network:
b de-excitation of the generator
b electrical shutdown by tripping.
De-excitation may be initiated in the following ways:
b by a command
v remote control command if enabled
v logic input if set up
b by logic equation or by Logipam to take into
account all specific generator installation
characteristics
b by delayed protection functions.
Installation Description
The electrical installation consists of a bus that connects to::
b a main supplied by a 10 MVA transformer
b a 3.15 MVA power generator
DE51602
N.O.
4 In normal operation, the generator and transformer are connected to the bus. The
generator provides backup power to the installation in the absence of the transformer
power supply. The installation is grounded by a neutral inductance. When the
generator is not connected to the network, its neutral is isolated. When faults occur,
the generator is over-excited for 3 - 10 seconds. Its fault current is equal to 3 times
its rated current. After the 3 - 10 seconds have elapsed, the fault current drops to 0.5
times the rated current.
The generator is protected:
b against network electrical short-circuits by a phase overcurrent protection
function 50/51 and a backup protection function 50V/51V
b against internal faults in generators by a generator differential protection
function 87M.
b against ground faults by a ground fault protection function 50N/51N when the
generator is connected to the bus and by a neutral voltage displacement
protection function when the generator is not connected
b against overloads by a thermal overload protection function 49RMS
b against unbalance by a negative sequence / unbalance protection function 46
b against frequency variations by underfrequency and overfrequency protection
functions 81L and 81H
b against voltage variations by undervoltage and overvoltage protection
functions 27 and 59
b against field loss by a protection function 40
b against faults due to the prime mover by a reverse active power protection
function 32P
b against loss of synchronization of the main network by a protection function
78PS.
Shutdown is total and not sequential. The genset shutdown and de-excitation time
delays are zero.
Description
The automatic transfer function is used to transfer bus supply from one source to
DE51498
another.
B80 B80 The function reduces bus supply interruptions, thereby increasing the service
M1 M2 continuity of the network supplied by the bus.
substation:
B80 B80 b "Main-main" transfer is suitable for dual-main substations without a tie
b "Main-tie-main" transfer is suitable for dual-main substations with a tie
M1 M
These two applications are described separately
F1 F2
Tie
F3
The automatic transfer function is symmetrical:
b hardware symmetry: dual-main substations, with two incoming circuit
4
breakers, and each main is protected by a Sepam Series 80 unit
b functional symmetry: automatic transfer is distributed between the two
Automatic transfer "MAIN-TIE-MAIN" with sync-check Sepam Series 80 units protecting the two mains.
managed by Sepam Series 80
Each function is described from the viewpoint of one of the two mains, the other main
being referred to as the "opposite side" main.
Equipment Used
DE51499
M1 M
At least two MES120 modules should be added to each Sepam.
Definition
The automatic "main-main" transfer is suitable for substations supplied by two mains
with no tie. This automatic transfer has two functions:
b automatic transfer with bus supply interruption
b voluntary return to normal without bus supply interruption.
N.O. N.C.
Description
N.C. N.O. N.O. N.O.
The function transfers bus supply from one source to the other after detecting a
M1 M2 M1 M2 M1 M2 voltage loss or fault upstream from the source.
Block Diagram
Description
N.O. N.C. N.C. N.C. N.C. N.O.
The voluntary return to normal without interruption involves two separate control
functions:
Transferred Condition Closed Transition Return to Normal b closing of the open incoming circuit breaker, with or without sync-check:
Condition the two incoming circuit breakers are closed
b then opening of the normally open circuit breaker, designated by the "NO
circuit breaker" selector.
These two functions may also be used to transfer the bus supply source without any
interruption.
Description
N.O. N.C. N.C. N.C.
Circuit breaker closing is ensured by the Switchgear control function, with or without
sync-check.
One Main Closed Two Mains Closed The AT function checks that all the required conditions are met and indicates to the
user that the return to normal is possible.
Block Diagram
DE52253
Description
N.C. N.C. N.C. N.O. This function controls the opening of circuit breakers that are designated "normally
open" by the position of the "NO circuit breaker" selector when the two main circuit
breakers are closed.
Two Mains Closed Return to Normal
One Main Closed For those automatic control sequences that put the two sources in parallel, it
guarantees that only one circuit breaker of the two is closed at the end of the transfer.
The open command is taken into account by the Switchgear control function.
Block Diagram
DE51586
Connection
DE51600
Close command
N.O. N.O.
: optional wiring.
4 Phase overcurrent
(ANSI 50/51)
Unit 1, instantaneous output
Detection of downstream
phase fault, to block automatic
transfer.
To be set according to
coordination study (the most
sensitive set point).
Ground fault (ANSI 50N/51N) Detection of downstream To be set according to
Unit 1, instantaneous output ground fault, to block coordination study (the most
automatic transfer. sensitive set point).
Phase overvoltage (ANSI 59) Detection of phase voltage Voltage set point: 90% VLLNp
Unit 1 upstream of the circuit Delay: 3 sec
breaker.
To be assigned to a Sepam
logic output in the control
matrix.
Optional Use Setting information
Protection Functions
Remnant undervoltage Detection of no remnant Voltage set point: 30% VLLNp
(ANSI 27R) voltage on the bus to which the Delay: 100 msec
Unit 1 motors are connected.
SFT2841: standard assignment of the inputs required for the The predefined outputs associated with the AT function are as follows:
AT function
"Protection" Button Description Use
59 - 1 Delayed output of the Phase Indication for the opposite side
overvoltage function (ANSI 59) Sepam: the voltage is OK
Unit 1 upstream of the incoming
circuit breaker.
"Logic" Button Description Use
NO circuit breaker closing Predefined output Automatic closing command of
V_CLOSE_NO_ORD opposite side circuit breaker.
Setting
Activity
Setting range On / Off
Voltage Return Time
Setting range 0 to 300 s
Accuracy (1) 2% or from 10 msec to +25 msec
Resolution 10 msec or 1 digit
Normal Tie Breaker Position
Setting range No tie / Normally open / Normally closed
Inputs
Designation Syntax Equations Logipam
Transfer command on fault V_TRANS_ON_FLT b b
Transfer off command V_TRANS_STOP b b
Outputs
Designation Syntax Equations Logipam Matrix
Automatic transfer on V_TRANSF_ON b
Tripping by 2/3 or 1/2 logic V_2/3_TRIPPING b b
Tripping by automatic V_AT_TRIPPING b b
transfer
NO circuit breaker closing V_CLOSE_NO_ORD b b
Breaker closing ready V_CLOSE_EN b b
(1) Under reference conditions (IEC 60255-6).
Definition
The "Main-Tie-Main" (M-T-M) transfer is automatic and is suitable for substations
with bus supplied by two mains and with a tie (M-T-M). Automatic transfer is made
up of two functions:
1 automatic transfer with bus supply interruption
2 voluntary return to normal without bus supply interruption.
Description
N.C. N.C. N.O. N.C. N.O. N.C. This function transfers bus supply from one source to the other after detecting a
N.O. N.O. N.C. voltage loss or a fault that is upstream of the source.
(1) (2) (3) Automatic source transfer takes place in two steps:
Automatic transfer with normally open tie 1 tripping the circuit breaker triggered by the detection of the loss of voltage or an
(1) Normal condition external trip command (trip command from upstream protection unit): loss of bus
(2) Transfer condition supply
(3) Transferred condition 2 closing the normally open circuit breaker to resupply the bus. According to the
parameter setting, the normally open circuit breaker may be one of the following:
b the tie circuit breaker, when the tie is normally open
b the opposite side circuit breaker, when the tie is normally closed.
DE51514
Initializing Transfer
Any of the following events can trigger automatic transfer:
b loss of voltage detected on the main by the Phase undervoltage function
(ANSI 27)
b or the detection of a fault by the protection units upstream of the main, with a
tripping command on the "External tripping 1" logic input
b or V_TRANS_ON_FLT, initialization of transfer by logic equations or by
Logipam.
Block Diagram
DE52289
4
Tie breaker or NO close blocked
If the normally open circuit breaker is the tie circuit breaker, the NO circuit breaker
closing command is transmitted by a Sepam logic output to close the circuit
breaker directly, without any intermediary.
Description
N.O. N.C. N.C. N.C. N.C. N.O.
The voluntary return to normal without interruption involves two separate control
N.C. N.C. N.C. functions:
1 closing the open circuit breaker with or without sync-check. The three circuit
(1) (2) (3) breakers are closed
Voluntary return to normal with normally closed tie 2 opening the normally open circuit breaker (designated by the "NO circuit breaker"
(1) Transferred condition selector).
(2) Closed Transition
(3) Return to normal condition
These two functions may also be used to transfer the bus supply source without any
interruption.
N.O. N.C. N.C. N.C. N.C. N.C. b the incoming circuit breaker is open
N.C. N.C. N.O.
b the opposite side circuit breaker and the tie circuit breaker are closed
b The voltage is OK upstream of the incoming circuit breaker. This voltage is
(1) (2) (3) detected either by function ANSI 59, or by a processing operation in Logipam
using V_TRANS_V_EN.
Voluntary return to normal with normally open tie
(1) Transferred condition
(2) Closed transition Optional Transfer Conditions
(3) Return to normal condition These conditions are required when the associated optional functions are enabled:
b the "Auto / Manual" selector is in the Manual position
b the three "Local / Remote" selectors are in the Local position
b the three circuit breakers are racked in
b no VT fault detected by the VT Supervision function (ANSI 60FL), to avoid
4
transfer on the loss of voltage transformers
b no blocking of transfer by V_TRANS_STOP by logic equations or by Logipam.
Description
N.O. N.C. N.C. N.C. Circuit breaker closing is ensured by the Switchgear control function, with or without
N.C.
sync-check.
N.C.
(1) (2) The AT function checks that all the required conditions are met and indicates to the
user that the return to normal is possible.
Closing the Open Circuit Breaker
(1) One Main open
(2) Two Mains closed Block Diagram
DE80146
U ,delayed
Description
N.C. N.C. N.C. N.O. This function controls the opening of the circuit breaker that is designated "normally
open" by the position of the "NO circuit breaker" selector, when the three circuit
N.C. N.C.
breakers are closed.
Return to normal with normally closed tie
For all automatic control sequences that put the two sources in parallel, it
guarantees, that only two of the three circuit breakers are closed at the end of the
transfer.
N.C. N.C. N.C. N.C.
N.C.
N.O. The open command is taken into account by the Switchgear control function.
Closing Tie
Description
The voluntary closing of the tie circuit breaker without interruption involves two
separate control functions:
1 closing the tie circuit breaker regardless of sync-check. The three circuit breakers
are closed.
2 opening the normally open circuit breaker, designated by the "NO circuit breaker"
selector.
Block Diagram
DE52257
Tie Breaker
: optional wiring
Phase overcurrent
(ANSI 50/51)
loss.
Detection of downstream
phase fault, to block automatic
To be set according to
coordination study (the most
4
Unit 1, instantaneous output transfer. sensitive set point).
Ground fault (ANSI 50N/51N) Detection of downstream To be set according to
Unit 1, instantaneous output ground fault, to block coordination study (the most
automatic transfer. sensitive set point).
Phase overvoltage (ANSI 59) Detection of phase voltage Voltage set point: 90% VLLNp
Unit 1 upstream of the circuit Delay: 3 sec
breaker.
To be assigned to a Sepam
logic output in the control
matrix.
Optional Use Setting Information
Protection Functions
Remnant undervoltage Detection of no remnant Voltage set point: 30% VLLNp
(ANSI 27R) voltage on the bus to which the Delay: 100 msec
Unit 1 motors are connected.
Setting
Activity
Setting range On / Off
Voltage Return Time
Setting range 0 to 300 s
Accuracy (1) 2% or from 10 ms to +25 ms
Resolution 10 ms or 1 digit
Normal Tie Position
Setting range No tie / Normally open / Normally closed
Inputs
Designation Syntax Equations Logipam
Transfer command on fault V_TRANS_ON_FLT b b
Transfer off command V_TRANS_STOP b b
Voltage OK upstream of the V_TRANS _ V_EN b
incoming circuit breaker
Outputs
Designation Syntax Equations Logipam Matrix
Automatic transfer on V_TRANSF_ON b
Tripping by 2/3 or 1/2 logic V_2/3_TRIPPING b b
Tripping by automatic V_AT_TRIPPING b b
transfer
NO circuit breaker closing V_CLOSE_NO_ORD b b
Breaker closing ready V_CLOSE_EN b b
b b
Tie tripping
Tie closing ready
Tie closing
V_TIE_OPENING
V_TIE_CLOSE_EN
V_TIE_CLOSING
b
b
b
b
4
Tie closing with sync-check V_TIESYNCFAIL b b
failed
(1) Under reference conditions (IEC 60255-6).
Operation
Events may be displayed locally on the front panel of Sepam by:
b a message on the display
b switching on of one of the 9 yellow LEDs.
The messages are visible on the Sepam display and on the SFT2841 Alarms
screen.
The number and type of predefined messages depend on the type of Sepam. The
table below gives the complete list of all predefined messages.
4 Buchholz alarm
Thermostat trip
BUCHHOLZ ALARM
THERMOST. TRIP
BUCHHOLZ ALARM
THERMOST. TRIP
Thermostat alarm THERMOST. ALARM THERMOST. ALARM
Pressure trip PRESSURE TRIP PRESSURE TRIP
Pressure alarm PRESSURE ALARM PRESSURE ALARM
Thermistor trip THERMISTOR TRIP THERMISTOR TRIP
Thermistor alarm THERMISTOR AL. THERMISTOR AL.
Control fault CONTROL FAULT CB CNTRL FAULT
Load shedding LOAD SHEDDING LOAD SHEDDING
Genset shutdown GENSET SHUTDOWN GENSET SHUTDOWN
De-excitation DE-EXCITATION DE-EXCITATION
Tripping command by automatic transfer AUTO TRANSFER AUTO TRANSFER
Diagnosis ANSI Code
SF6 fault SF6 LOW SF6 LOW
MET1482 No 1 RTD fault RTDS FAULT MET1 (1) RTDS FAULT NO. 1 (1)
MET1482 No 2 RTD fault RTDS FAULT MET2 (1) RTDS FAULT NO. 2 (1)
VT supervision 60FL Phase VT supervision VT FAULT VT FAULT
Residual VT supervision VT FAULT Vo VT FAULT Vr
CT supervision 60 Main CT supervision CT FAULT CT FAULT
Additional CT supervision CT FAULT CT FAULT
Trip circuit supervision (TCS) fault or 74 TRIP CIRCUIT TRIP CKT FAULT
mismatching of open/closed position contacts
Closing circuit fault CLOSE CIRCUIT CLOSE CIRCUIT
Capacitor step matching fault COMP. FLT. STP (1 to 4) BANK. FLT. STP (1 to 4)
Cumulative breaking current monitoring IBREAKING >> IBREAKING >>
Battery monitoring BATTERY LOW (1) BATTERY LOW (1)
Auxiliary power supply monitoring Low threshold LOW POWER SUP. LOW POWER SUP.
High threshold HIGH POWER SUP. HIGH POWER SUP.
(1) RTD FAULT, BATTERY LOW messages: refer to the maintenance chapter.
(2) With indication of the faulty phase.
(3) With indication of the faulty phase, when used with phase-to-neutral voltage.
Field loss
Negative sequence / unbalance
40
46
Tripping OVER TEMP. TRIP
FIELD LOSS
UNBALANCE I
OVER TEMP. TRIP
LOSS OF FIELD
CURRENT UNBAL
4
Negative sequence overvoltage 47 UNBALANCE U VOLTAGE UNBAL
Excessive starting time, locked rotor 48/51LR Excessive starting time LONG START LONG START
Locked rotor in normal operation ROTOR BLOCKING JAMMED / STALL
Locked rotor on start LOCKED ROTOR STRT LOCKED ROTR
Thermal overload 49RMS Alarm THERMAL ALARM THERMAL ALARM
Tripping THERMAL TRIP THERMAL TRIP
Block closing START INHIBIT BLOCKED START
Breaker failure 50BF BREAKER FAILURE BREAKER FAILURE
Inadvertent energization 50/27 INADV. ENERGIZ. INADV. ENERGIZ.
Phase overcurrent 50/51 PHASE FAULT (2) PHASE FAULT (2)
Ground fault 50N/51N EARTH FAULT GROUND FAULT
Voltage-restrained overcurrent 50V/51V O/C V REST (2) O/C V REST (2)
Capacitor bank unbalance 51C UNBAL. STP (1 to 4) UNBAL. STEP (1 to 4)
Overvoltage 59 OVERVOLTAGE (1) OVERVOLTAGE (1)
Neutral voltage displacement 59N Vo FAULT Vr FAULT
Restricted ground fault 64REF RESTRIC. EARTH RESTRIC. GROUND
FAULT FAULT
Starts per hour 66 START INHIBIT BLOCKED START
Directional phase overcurrent 67 DIR. PHASE FAULT (2) DIR. PHASE FAULT (2)
Directional ground fault 67N/67NC DIR. EARTH FAULT DIR. GROUND FAULT
Pole slip 78PS POLE SLIP POLE SLIP
Recloser 79 Cycle x CYCLE (1 to 4) (3) SHOT (1 to 4) (3)
Reclosing successful CLEARED FAULT CLEARED FAULT
Permanent trip FINAL TRIP FINAL TRIP
Overfrequency 81H OVER FREQ. OVER FREQ.
Underfrequency 81L UNDER FREQ. UNDER FREQ.
Rate of change of frequency 81R ROCOF df/dt
Machine differential 87M DIFFERENTIAL DIFFERENTIAL
Transformer differential 87T DIFFERENTIAL DIFFERENTIAL
(1) With indication of the faulty phase, when used with phase-to-neutral voltage.
(2) With indication of the faulty phase.
(3) With indication of the protection unit that has initiated the cycle (phase fault, ground fault, ...).
LED Indication
The 9 yellow LEDs on the front of Sepam are assigned by default to the following
events:
LED Event Name on Label
on Front Panel
LED 1 Trip protection 50/51 unit 1 I>51
LED 2 Trip protection 50/51 unit 2 I>>51
LED 3 Trip protection 50N/51N unit 1 Io > 51N
LED 4 Trip protection 50N/51N unit 2 Io >> 51N
LED 5 Ext
LED 6
LED 7 Circuit breaker open (Ia02) 0 Off
LED 8 Circuit breaker closed (Ia01) I On
LED 9 Trip by circuit breaker control Trip
The default parameter setting can be personalized using the SFT2841 software.
LEDs are assigned to events in the "LEDs" tab of the control matrix screen. Editing
and printing of personalized labels are proposed in the general characteristics
screen.
Description
Switchgear can be controlled locally using Sepam Series 80 units equipped with
PE50486
In Remote mode, remote control commands are taken into account. Local control
commands are disabled, with the exception of the circuit breaker open command.
Remote mode is indicated by the variable V_MIMIC_REMOTE = 1.
In Local mode, remote control commands are disabled, with the exception of the
Local control using the mimic-based UMI circuit breaker open command. Local control commands are enabled. Local mode
is indicated by the variable V_MIMIC_LOCAL = 1.
The mimic diagram editor integrated in the SFT2841 software can be used to
personalize and setup mimic diagrams.
The symbols that make up the mimic-diagram constitute the interface between the
mimic-based UMI and the other Sepam control functions.
This type of symbol is used for circuit breakers, for example. The symbol
outputs are used to control the electrotechnical device:
v directly via the Sepam logic outputs
v by the switchgear control function
v by logic equations or the Logipam program.
Symbol Animation
Symbols change, depending on the value of their inputs. A graphic symbol
represents each state. Animation occurs automatically by changing the symbol each
time the state changes.
The symbol inputs must be assigned directly to the Sepam inputs to indicate the
position of the symbolized switchgear.
This type of symbol is used for simple presentation of information, for example the
racked out position of a circuit breaker.
Input = 1 Active
4
Animated Symbols with Two Inputs
"Animated - 2 inputs" and "Controlled - 2 inputs/outputs" symbols are animated
symbols with two inputs, one open and the other closed. This is the most common
situation in representing switchgear positions.
The symbol has three states,or graphic representations: open, closed, and unknown.
The latter occurs when the inputs are not matched. In this case it is impossible to
determine the position of the switchgear.
Blocking Commands
"Controlled - 1 input/output" and "Controlled - 2 inputs/outputs" symbols have two
block inputs that, when set to 1, block opening and closing commands. This makes
it possible to create interlocking systems or other command-disabling systems that
are taken into account by the UMI.
Symbol Inputs/Outputs
Depending on the desired operation of the mimic-based UMI, Sepam variables
must be assigned to the inputs of animated symbols and the inputs/outputs of
controlled symbols.
Block Diagram
The block diagrams below present the functions ensured by the controlled symbols,
based on two examples.
4
Voluntary user control commands (selection of the device to be controlled in the
mimic diagram and action on a control key) are represented in the block diagrams by
the following icons:
: open command
: close command
DE51591
DE51592
Description
The control matrix is used for assigning the logic outputs and LEDs to data produced
by the protection functions, control logic, and logic inputs.
Each column creates a logic OR between all the lines selected. The matrix can also
be used to display the alarms associated with the data. It guarantees the
consistency of the parameter setting with the predefined functions.
The following data are managed in the control matrix and can be set using the
SFT2841 software tool.
4 "Logic" Button
Switchgear Control
Meaning Comments
Closing Closing by switchgear control function By default on O3. Only available if switchgear
control is in circuit breaker mode
Tripping Tripping by switchgear control function Forced on O1, if switchgear control is in circuit
breaker mode
Block closing Block by switchgear control function By default on O2. Only available if switchgear
control is in circuit breaker mode
Contactor control Contactor control Forced on O1, if switchgear control is in circuit
breaker mode
Pick-up Logic OR of the instantaneous output of all protection units with
the exception of protection units 38/49T, 48/51LR, 49 RMS,
64G2/27TN, 66.
Drop-out A protection unit time delay counter has not yet gone back to 0.
Zone Selective Interlocking
Zone selective Interlocking trip Tripping command sent by zone selective interlocking function Only when zone selective interlocking function is
used without switchgear control function
Blocking send 1 Sending of blocking signal to next Sepam in zone selective By default on O102.
interlocking chain 1
Blocking send 2 Sending of blocking signal to next Sepam in zone selective By default on O103
interlocking chain 2
Motor/Generator Control
Load shedding Sending of a load shedding command Motor application
Genset shutdown Sending of a prime mover shutdown command Generator application
De-excitation Sending of a de-excitation command Generator application
Recloser
Recloser in service The recloser is in service
Reclosing successful The recloser has successfuly reclosed Pulse type output
Permanent trip The circuit breaker is permanently open after the reclosing cycles Pulse type output
Recloser ready The recloser is ready to operate
Recloser step 1 Step 1 in progress
Recloser step 2 Step 2 in progress
Recloser step 3 Step 3 in progress
Recloser step 4 Step 4 in progress
Closing by recloser A closing command is given by the recloser
Example:
Va = P5051_2_3 OR Ia02.
The variable Va is assigned the result of the logic OR operation involving the value
from protection function 50/51 and logic input Ia02. The variables may be used for
other operations or as outputs to produce actions in the control matrix, protection
functions or predefined control and monitoring functions.
Description of Operations
Operators
b =: assignment of a result
SFT2841: logic equation editor. Vb = VL3 //Vb is assigned the value of VL3
b NOT: logic inversion
VL1 = NOT VL2 // VL1 is assigned the opposite logic state of VL2
PE50461
b OR: logic OR
Va = VL3 OR I103 // Va is assigned state 1 if VL3 or I103 are in state 1
b AND: logic AND
VV3 = VL2 AND VVa // VV3 is assigned state 1 if VL2 and VV1 are in state 1
b XOR: exclusive OR
V3 = VL1 XOR VL2 // V3 is assigned state 1 if only one of the variables VL1
or VL2 is in state 1.
This is equivalent to V3 = (Va AND (NOT Vb)) OR (Vb AND (NOT Va))
b //: commentary
The characters on the right are not processed
b (,): the operations may be grouped between brackets to indicate the order in
which they are carried out
V1 = (VL3 OR VL2) AND I213.
Functions
b x = SR(y, z): bistable with priority to Set
x is set to 1 when y is equal to 1
x is set to 0 when z is equal to 1 (and y is equal to 0)
otherwise x is not changed.
V1 = SR(I104, I105) // I104 sets V1 to 1, I105 sets V1 to 0
b LATCH(x, y, ): latching of variables x, y, ...
The variables are maintained constantly at "1" after being initially set. They are reset
to "0" when Sepam is reset (reset button, external input or remote control
command).
The LATCH function accepts as many parameters as the number of variables that
the user wishes to latch. It applies to the entire program, whatever the position of
LATCH in the program. For easier reading, it is advisable to put it at the beginning of
the program.
LATCH(V1, VL2, VV3) // V1, VL2 and VV3 are latched. Once they are set to 1, only
a Sepam reset can set them back to 0
b x = TON(y, t): "on" delay timer
The variable x goes to 1 t ms after variable y goes to 1.
DE50621
x = TON(y, t).
Input vVariables
Type Syntax Example / Meaning
Logic inputs Ixxx I101: input 1 of MES120 No 1 module
I312 : input 12 of MES120 No 3 module
Protection function outputs Pnnnn_x_y P50/51_2_1 : Protection 50/51, unit 2, delayed output.
nnnn: ANSI code The protection function output data numbers are given in the
x: unit characteristics of each function and may be accessed using the
y: data data input assistance tool.
Remote control commands TC1 to TC64 Pulse type value (duration of one 14 ms cycle) of remote control
commands received
Predefined control function outputs V_TRIPPED Tripping command present at switchgear control function output
V_BLOCK_CLOSE Block closing command present at switchgear control function
output
V_CLOSED Closing command present at switchgear control function output
Mimic-based UMI outputs V_MIMIC_OUT_1 to Variables that may be assigned to the mimic diagram symbol
V_MIMIC_OUT_16 outputs and that change values when control commands are
transmitted from the mimic-based UMI
V_MIMIC_LOCAL Position of the key on the mimic-based UMI
V_MIMIC_TEST,
V_MIMIC_REMOTE
Output Variables
Type Syntax Example / Meaning
Outputs to matrix V1 to V20 They may initiate LEDs, logic outputs or messages in the matrix.
Protection function inputs Pnnnn_x_y P50N/51N_6_113: Protection 50N/51N, unit 6, block command.
nnn: ANSI code The protection function output data numbers are given in the
x: unit characteristics of each function and may be accessed using the
4 Predefined control function inputs
y: data
V_TRIPCB
data input assistance tool.
Tripping of circuit breaker (contactor) by the switchgear control
function. Used to adapt tripping and recloser activation conditions.
V_BLOCKCLOSE Block circuit breaker (contactor) closing by the switchgear control
function. Used to add circuit breaker (contactor) block closing
conditions.
V_CLOSECB Closing of circuit breaker (contactor) by the switchgear control
function. Used to generate a circuit breaker (contactor) close
command based on a particular condition.
V_SHUTDOWN Shutdown of genset prime mover. Used to adapt cases of genset
shutdown
V_DE_EXCITATION Generator de-excitation
Used to adapt cases requiring generator de-excitation
V_FLAGREC Data saved in disturbance recording.
Used to save a specific logic state in addition to those already
present in disturbance recording.
V_RESET Sepam reset
V_CLEAR Clearing of alarms present
V_BLOCK_RESET_LOCAL Block Sepam reset by UMI Reset key.
V_CLOSE_NOCTRL Breaking device closing enabled without sync-check.
Used to adapt the Switchgear control function
V_TRIP_STP1 to Tripping of capacitor steps 1 to 4.
V_TRIP_STP4 Used to adapt the Capacitor step control function
V_CLOSE_STP1 to Closing of capacitor steps 1 to 4.
V_CLOSE_STP4 Used to adapt the Capacitor step control function
V_TRANS_ON_FLT Automatic transfer command on fault.
Used to adapt automatic transfer
V_TRANS_STOP Stopping automatic transfer
Used to adapt automatic transfer
Local Variables, Constants
Type Syntax Example / Meaning
Local variables stored VL1 to VL31 The values of these variables are saved in the event of an auxiliary
power outage and are restored when Sepam starts again.
Local variables not stored VV1 to VV31 The values of these variables are not saved in the event of an
auxiliary power outage. They are assigned the value of 0 when
Sepam starts.
Constants K_1, K_0 Value not modifiable
K_1: always 1
K_0 : always 0
Examples of Applications
The following are some application examples.
1 Latching the recloser permanent trip signal. By default, this signal is of the
pulse type at the recloser output. If required by operating conditions, it may be
latched as follows:
4
LATCH (V1) // V1 may be latched
V1 = P79_1_204 // recloser "permanent trip" output.
V1 may then control a LED or output relay in the matrix.
2 Latching an LED without latching the protection function. Certain operating
conditions call for the latching of indications on the front panel of Sepam,
without latching of the tripping output O1.
LATCH (V1, V2) // V1 and V2 may be latched
V1 = P50/51_1_1 OR P50/51_3_1 // tripping, units 1 and 3 of protection 50/51
V2 = P50/51_2_1 OR P50/51_4_1 // tripping, units 2 and 4 of protection 50/51
V1 and V2 must be configured in the matrix to control 2 front panel LEDs.
3 Circuit breaker tripping if input I113 is present for more than 300 ms.
V_TRIPCB = TON (I113, 300).
4 Live line work (example 1). If work is underway with power on (indicated by
input I205), the relay behavior is to be changed as follows:
a) circuit breaker tripping by the instantaneous output of protection 50/51 unit 1
or 50N/51N unit 1 AND if input I205 is present:
V_TRIPCB = (P50/51_1_1 OR P50N/51N_1_1) AND I205
b) Block recloser:
P79_1_113 = I205
5 Live line work (example 2). The user wishes to block protection functions 50N/
51N and 46 by an input I204:
P50N/51N_1_113 = I204
P46_1_113 = I204
6 Validation of a 50N/51N protection function by logic input I210. A 50N/51N
protection function with a very low threshold must only initiate tripping of the
circuit breaker if it is validated by an input. The input comes from a relay which
gives a very accurate measurement of the neutral point current:
V_TRIPCB = P50N/51N_1_3 AND I210
7 Block circuit breaker closing if thermal alarm thresholds are overrun. The
temperature protection function 38/49T supplies 16 alarm bits. If one of the first
three bits is activated (1 state), the user wishes to block circuit breaker closing
V_BLOCKCLOSE = P38/49T_1_10 OR P38/49T_2_10 OR P38/49T_3_10
8 Remote control command to block protection 50/51 unit 1.
VL1=SR(TC63,TC64) // TC63 set block, TC64 reset blocking
P50/51_1_113 = VL1 // VL1 is stored in the event of an auxiliary power outage.
Only the Sepam Series 80 with a cartridge containing the Logipam SFT080
option can run the control and monitoring functions programmed by Logipam.
Operating principle
DE51891
4
Logipam Programming Software
The Logipam SFT2885 programming software can be used to:
PE50257
The ladder-language program and the data used can be documented and a complete
file can be printed.
Offering more possibilities than the logic-equation editor, Logipam can be used to
SFT2885: Logipam programming software. create the following functions :
b specific automatic transfer functions
b motor starting sequences.
Appendix Contents
A Method Measurement
Number Method
Setting Range
Zero
Sequence CT
Connections
Residual
Current
Setting
Remark
6A* External Sum of DT=0.1 to 15 INr CSH 30 Zero A B C 1 A CT + Set Sepam Series
Phase CT IDMT=0.1 to INr Sequence CT as 4 CSH or 5 A 80 For INr=IN
Secondaries (1 A Interface 1 CT + CSH (Primary Rated
5
or 5 A) 2 Current: 1 A to 6.25
6 kA)
P2 P1 3
6A External Sum of DT=0.1 to 15 INr CSH 30 Zero S1 S2 CSH 30 B 1 A CT + CSH INr=IN/10 (Ipri=1 A to
Core
(Sensitive) Phase CT IDMT=0.1 to INr Sequence CT as 5 A CTs Balance (or 5 A CT + 6.25 kA)
CT
Secondaries (1 A Interface 14 (17) CSH)
Sepam
or 5 A) Series 80 sensitivity X10
5 A CT: 4 Turns
1 A CT: 2 Turns 15 (18)
*See alternate CSH30 secondary connection in the Sepam Series 80 Installation, Use, Commissioning and Maintenance manual.
Note: INr should be thought of as a relay input port for ground fault protection. This port can accept residually connected phase ct's and therefore measure positive,
negative and zero sequence components. This port can also accept a zero sequence ct which measures only true zero sequence (no positive or negative
sequence). So the port name INr is just that a port name. What kind of current (positive, negative or zero sequence) depends on the type of CTs used)
Method Measurement
Number Method
Setting Range
Zero Sequence
CT
Connections
Residual
Current Remark A
Setting
2B Specific CSH Zero DT=0.2 A to 30 A CSH 120 A B C N 2 A Rated Sepam Series 80
Sequence CT On 2 CSH 200 CSH (2 A Core Considers INr=2 A
IDMT=0.2 A to 2 A
A Input Rating Bal. CT)
14 (17)
P1 S2
3B Specific CSH Zero DT=0.5A to 75A CSH 120 Sepam 5 A Rated INr=5A
Series 80
Sequence CT on 5 CSH 200 P2 CSH (5 A zero
IDMT=0.5A to S1 15 (18)
A Input Rating sequence CT)
7.5A E
Shield CSH Core Balance CT
4B Specific CSH Zero DT=2 A to 300 A CSH 120 20 A Rated Sepam Series 80
Sequence CT On IDMT=2 A to 20 A CSH 200 CSH (20 A Considers INr=20 A
20 A Input Rating Core Bal. CT)
5B* Standard 1 A CT or DT=0.1 to 15 INr 1 A/5 A CT Zero 1 A CT + CSH Primary Rated
5 A CT IDMT=0.1 to INr Sequence CT + A B C N or 5 ACT + Current: 1 A to 6.25
CSH 30 Aux CT 5 A = 4 Turns CSH kA, INr=IN
as interface 1 A = 2 Turns
14 (17)
P1 S1 P1 S2
Sepam
5B Standard 5 A CT or DT=0.1 to 15 INr 5 A/1 A CT Zero Series 80 5 A CT + CSH Primary Rated
(Sensitive) 1 A CT IDMT=0.1 to INr Sequence CT + P2 S2 P2 S1 15 (18) (or 1 A CT + Current: 1 A to 6.25
CSH 30 CT
CSH 30 Aux CT CSH) kA, INr=IN/10
E
as interface Shield
sensitivity X10
6B* External Sum of DT=0.1 to 15 INr CSH 30 Zero A B C N 1 A CT + CSH Set Sepam Series
Phase CT Sequence CT as or 5 A CT + 80 For INr=IN
IDMT=0.1 to INr 4
Secondaries (1 A Interface 1 CSH (Primary Rated
5
or 5 A) 2 Current: 1A to 6.25
6 kA)
3
6B External Sum of DT=0.1 to 15 INr CSH 30 Zero B 1 A CT + CSH INr=IN/10 (Ipri=1 A to
(Sensitive) Phase CT Sequence CT as P2 P1 (or 5 A CT + 6.25 kA)
IDMT=0.1 to INr S1 S2
CSH 30
Secondaries (1 A Interface 1 A CTs Core 14 (17) CSH) sensitivity
Balance
or 5 A) CT Sepam
X10
Series 80
5 A CT: 4 Turns 15 (18)
1 A CT: 2 Turns E
*See alternate CSH30 secondary connection in the Sepam Series 80 Installation, Use, Commissioning and Maintenance manual.
Note: INr should be thought of as a relay input port for ground fault protection. This port can accept residually connected phase ct's and therefore measure positive,
negative and zero sequence components. This port can also accept a zero sequence ct which measures only true zero sequence (no positive or negative
sequence). So the port name INr is just that a port name. What kind of current (positive, negative or zero sequence) depends on the type of CT's used)
Setting Coding
A Data Format
All the settings are transmitted in 32-bit signed 2's complement integer format.
Protection Settings
They are organized according to increasing ANSI codes.
ANSI 12 - Overspeed
A
Function number: 72xx
Unit 1: xx = 01 to unit 2: xx = 02
Setting Data Format/Unit
1 to 3 Common settings
4 Reserved
5 Set point %
6 Tripping time delay 10 ms
ANSI 14 - Underspeed
Function number: 77xx
Unit 1: xx = 01 to unit 2: xx = 02
Setting Data Format/Unit
1 to 3 Common settings
4 Reserved
5 Set point %
6 Tripping time delay 10 ms
ANSI 27 - Undervoltage
Function number: 32xx
Unit 1: xx = 01 to unit 4: xx = 04
Setting Data Format/Unit
1 to 4 Common settings
5 Tripping curve 0: definite
19: IDMT
6 Voltage mode 0: phase-to-neutral
1: phase-to-phase
7 Threshold voltage % VLLp
8 Tripping time delay 10 ms
ANSI 59 - Overvoltage
Function number: 28xx
Unit 1: xx = 01 to unit 4: xx = 04
Setting Data Format/Unit
1 to 4 Common settings
5 Voltage mode 0: phase-to-neutral
1: phase-to-phase
6 Threshold voltage % VLLp
7 Tripping time delay 10 ms
ANSI 79 - Recloser
Function number: 1701
A 1
Setting Data
Reserved
Format/Unit
2 Reserved
3 Common settings
4 Reserved
5 Number of shots 0 to 4
6 Reclaim time 10 ms
7 Safety time until ready 10 ms
8 Maximum additional dead time 0: no
1: yes
9 Maximum wait time 10 ms
10 Step 1 activation mode see note
11 Step 2, 3, 4 activation mode see note
12 Step 1 dead time 10 ms
13 Step 2 dead time 10 ms
14 Step 3 dead time 10 ms
15 Step 4 dead time 10 ms
General Parameters
These settings are read accessible only.
Function number: D002
Setting Data Format/Unit
A
1 Working language 1: English 2: other
2 Rated frequency 50, 60 (Hz)
3 Active group of settings 1: group A 2: group B
3: selection by logic input
4: selection by remote control
4 Demand-value integration period 5, 10, 15, 30, 60 minutes
5 Type of cubicle 1: main 2: feeder
6 Active-energy increment 100 to 5000000 (W)
7 Reactive-energy increment 100 to 5000000 (var)
8 Phase-rotation direction 1: direction 123 2: direction 132
9 Temperature unit 1: C 2: F
10 Remote-setting authorization 1: no 2: yes
11 Time synchronization mode 1: COM1 port 2: COM2 port
3: input I103 5: none
12 Remote-control mode 1: SBO mode 2: direct mode
13 Reserved
14 Monitoring of auxiliary power 1: inactive 2: active
15 Rated auxiliary voltage 24 to 250 (V DC)
16 Aux. voltage alarm low set point % rated Vaux, min. 20 V
17 Aux. voltage alarm high set point % rated Vaux, max. 275 V
18 Logic inputs ignored on loss of Vaux 1: inactive 2: active
19 Base current IB 0.2 to 1.3 IN (A)
20 Rated current IN 1 to 6250 A
21 Number of phase CTs 1: 2 CTs 2: 3 CTs
22 Phase CT rating 1: 1 A 2: 5 A3: LPCT
23 Rated residual current INr 10 to 62500 (dA)
24 Residual current measurement mode 1: CSH 2 A 3: CSH 20 A
4: CSH + CT 1 A 6: CSH + CT 5 A
8: ACE990 range 1
9: ACE990 range 2
11: not measured
25 Reserved
26 Rated primary voltage VLLp 220 to 250000 (V)
27 Rated secondary voltage VLLs 100, 110, 115, 120, 200, 230 (V)
28 VT wiring 1: 3 VLn, 2: 2 VLL, 3: 1 VLL, 4: 1 VLn
29 Residual voltage mode 1: none 2: 3V
3: VT VLLs/3 4: VT VLLs/3
30 Neutral-point residual voltage measurement 1: none 2: present
31 Neutral-point rated voltage VLLp 220 to 250000 (V)
32 Neutral-point rated voltage VLLs 57 V to 133 V
33 Reserved
34 Reserved
35 Additional rated current I'n 1 to 6250 A
36 Number of additional phase CTs 1: 2 CTs 2: 3 CTs3: none
37 Additional phase CT rating 1: 1 A 2: 5 A3: LPCT
38 Additional rated residual current I'Nr 10 to 62500 (dA)
39 Additional residual current measurement mode Idem 24
40 Reserved
41 Reserved
42 Reserved
43 Reserved
44 Reserved
45 Reserved
46 Reserved
47 Reserved
48 Reserved
Application-Specific Parameters
These settings are read accessible only.
Function number: D003
Setting Data Format/Unit
1 Transformer presence 1: no 2: yes
2 Voltage winding 1 VLL1 220 to 250000 V
3 Voltage winding 2 VLL2 220 to 440000 V
4 Power S 100 to 999000 kVA
5 Vector shift 0 to 11
6 Rated motor speed 100 to 3600 rpm
7 Number of pulses per rotation 1 to 1800
8 Zero speed threshold 5 to 20%
Appendix
Appendix
Appendix
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