PROTECTIVE RELAY SETTING & COORDINATION STUDY
Timor-1
Coal Fired Steam Power Plant 2 X 50 MW
(Timor-1 CFSPP Project)
Consortium of
PT IKPT - PT PP (Persero) Tbk. - ITOCHU Corporation Sumitomo Heavy Industries, Ltd. - PT Medco Power Indonesia
Date:
B
MECHANICAL
ELECTRICAL
REVIEW
☐
☐
A
CIVIL
Comm No:
APPROVED
NOTED
APPROVED AS
C
☐
NOT APPROVED
I
☐
INFORMATION
T1-PP-000-ELE-STU-00003
PLN UPP TIMOR
Date:
Log
out
SUPPORT
PLN UIP NUSRA (HO)
REVIEWED DOES NOT RELIEVE
CONTRACTOR FROM RESPONSIBILITY
FOR ERROR OR DEVIATIONS FROM
CONTRACT REQUIREMENTS
By:
PLN DOC. NO.:
I&C
CONTRACTOR DOC. NO. :
Date:
DISTRIBUTION
Log
in
PLN PUSENLIS (JKT)
✓
CONTRACT NO. :
0389.PJ/DAN.02.01/010000/2019
JAYA CM (SITE)
CONTRACTOR (JKT)
✓
CONTRACTOR (SITE)
Comm No:
Note:
0
2022-09-05
REV
DATE
Issued for Approval
PURPOSE OF ISSUE
PREPARED
CHECKED
APPROVED
AUTHORIZED
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2022-08-30
Project Document No: T1-PP-000-ELE-STU-00003
REVISION HISTORY
REV. NO.
DATE
0
2022-09-05
DESCRIPTION
Issued for Approval
REV. 1
Page 2 of 17
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
1.
2.
3.
4.
5.
6.
7.
8.
9.
2022-08-30
Project Document No: T1-PP-000-ELE-STU-00003
REV. 1
Page 2 of 17
TABLE OF CONTENT
GENERAL .................................................................................................................................................... 4
CODE AND STANDARD ............................................................................................................................. 4
REFFERENCE DOCUMENT ....................................................................................................................... 4
LANGUAGE AND SYSTEM OF UNITS ...................................................................................................... 4
PRINCIPLES OF PROTECTIVE RELAY APPLICATION ........................................................................... 4
DESIGN BASIS ............................................................................................................................................ 4
COORDINATION RELAY ............................................................................................................................ 5
METHODOLOGY AND CALCULATION CRITERIA................................................................................... 7
8.1 Study Case .......................................................................................................................................... 10
CONCLUSION ............................................................................................................................................. 17
ATTACHMENT
ATTACHMENT 1.
: SINGLE LINE DIAGRAM
ATTACHMENT 2.
: TABLE SETTING FOR PROTECTION RELAY
ATTACHMENT 3.
: COORDINATION CURVE
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
1.
2022-08-30
Project Document No: T1-PP-000-ELE-STU-00003
REV. 1
Page 2 of 17
GENERAL
This document covers the calculation of protection relay coordination study and shall constitute the
setting of each breaker and relays for TIMOR-1 CFSPP (2 x 50 MW) at Kupang, Nusa Tenggara
Timur Province, Indonesia. The result of the calculation is used to determine the setting rating relay.
2.
CODE AND STANDARD
All calculation shall be in accordance with:
International Standards
IEEE Std. 141-1993
IEEE Std. 399-1997
: Recommended Practice for Electric Power Distribution for Industrial Plants
: Recommended Practice for Industrial and Commercial Power System
Analysis
IEEE Std. 242-1986 : Recommended Practice for Protection and Coordination of Industrial and
Commercial Power Systems
IEEE C37.101-1993 : Guide for AC Generator Ground Protection
IEEE C37.102-1987 : Guide for AC Generator Protection
IEC 60909
: Short Circuit Current Calculation in Three-phase A.C. Systems
IEC 60255
: Measuring Relays and Protection Equipment
3.
REFFERENCE DOCUMENT
The electrical system configuration and load data are
a. Electrical Load Data Calculation
b. Overal Single Line Diagram
c. SLD For MV 6.3 kV Medium Voltage System
d. SLD For LV 400/230 V AC Low Voltage System
4.
based on the list below:
(T1-PP-000-ELE-CAL-00002)
(T1-PP-000-ELE-SLD-00002)
(T1-PP-000-ELE-SLD-00003)
(T1-PP-000-ELE-SLD-00004)
LANGUAGE AND SYSTEM OF UNITS
All units of measurement shall be in the metric system. All documents to be submitted shall be written
in English.
5.
PRINCIPLES OF PROTECTIVE RELAY APPLICATION
This power load flow study is performed using computer software analysis program ETAP. The
calculations using load flow analysis which is based on Newton-Raphson method. Load Flow Analysis
calculates the bus voltages, branch power factors, currents, and power flows throughout the electrical
system.
6.
DESIGN BASIS
Protection is arranged to cover the electrical power system completely, leaving no parts unprotected.
When fault occurs, the protection is required to selectivity to trip only the nearest circuit breakers.
This concept of protection is so called discrimination or selectivity.
For time graded protection as presented in this report, the tripping time is inversely proportional to the
fault current level for any given protective gears and the actual characteristic is a function of both the
time and current settings.
The protective gears in the successive zones are set to operate in time, which is graded through the
sequence of equipment, such that upon the occurrence of a fault, only the protective gear nearest of
the fault will complete the tripping function although more than one protective gear will response.
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
7.
2022-08-30
Project Document No: T1-PP-000-ELE-STU-00003
REV. 1
COORDINATION RELAY
The overall protective element used in the system is summarized below:
a. Incoming 150 kV to GT (HV)
Differential Protection Relay
Circuit Breaker (CB) 50 kA, 150 kV, 300 A.
Protective elements:
•
•
•
•
•
•
•
•
Differential Transformer Protection (87 GT)
Restricted Earth Fault (64 REF)
Over Current (50/51)
Earth Fault (50N/51N)
Transformer Over Winding Temperature (49 WT)
Transformer Over Oil Temperature (49 OT)
Transformer Gas Protection/Buchholz For Main Tank and OLTC (63)
Transformer Over Flux Protection (24)
b. Incoming 150 kV to GT (LV)
Differential Protection Relay
Circuit Breaker (CB) 50 kA, 15 kV, 4000 A.
Protective elements:
•
•
•
c.
Restricted Earth Fault (64 REF)
Over Current (50/51)
Earth Fault (50N/51N)
Outgoing 15 kV to UAT (HV)
Differential Protection Relay
Vacuum Circuit Breaker (VCB) 50 kA, 15 kV, 630 A.
Protective elements:
•
•
•
•
•
•
•
•
d.
Differential Transformer Protection (87 UAT)
Restricted Earth Fault (64 REF)
Over Current (50/51)
Earth Fault (50N/51N)
Transformer Over Winding Temperature (49 WT)
Transformer Over Oil Temperature (49 OT)
Transformer Gas Protection/Buchholz for Main Tank and OLTC (63)
Standby Earth Fault for NGR (SBEF)
Outgoing 15 kV to UAT (LV)
Differential Protection Relay
Vacuum Circuit Breaker (VCB) 25 kA, 6,3 kV, 1600 A.
Protective elements:
•
•
Restricted Earth Fault (64 REF)
Over Current (50/51)
Page 2 of 17
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2022-08-30
•
Project Document No: T1-PP-000-ELE-STU-00003
REV. 1
Page 2 of 17
Earth Fault (50N/51N)
e. Incoming 15 kV from Generator
Generator Protection relay
Vacuum Circuit Breaker (VCB) 50 kA, 15 kV, 4000 A.
Protective elements:
f.
•
•
•
•
•
•
•
•
•
•
•
•
•
•
Generator 100% Stator Earth Fault Protection (59G)
Generator Differential Protection (87G)
Overall Differential Protection (87O)
Generator Negative Phase Sequence Protection {46)
Generator Loss of Excitation Protection (40)
Generator Over-Excitation (V/Hz) Protection (24)
Generator Reverse Power Protection (32)
Generator Overvoltage Protection (59)
Generator Under voltage Protection (27)
Generator Voltage Controlled Over current relay (51V)
Generator Rotor Earth Fault (64F)
Impedance Protection (21)
Voltage Balance Protection ("60)
Frequency Protection (81)
•
•
Generator Out of Step Protection (78)
Generator Stator Thermal Protection ( 49) Over current and Earth Fault Protection (50/51:
50N/51 N)
Incoming 6.3 kV from UAT
Vacuum Circuit Breaker (VCB) 25 kA, 6.3 kV, 1600 A.
Protective elements:
•
•
•
•
•
•
•
•
g.
Medium Voltage System Protection
-
h.
Differential Transformer Protection (87 UAT)
Restricted Earth Fault (64 REF)
Over Current (50/51)
Earth Fault (50N/51N)
Transformer Over Winding Temperature (49 WT)
Transformer Over Oil Temperature (49 OT)
Transformer Gas Protection/Buchholz for Main Tank and OLTC (63)
Standby Earth Fault for NGR (SBEF)
Outgoing 6.3 kV to Electric Motor
Air Circuit Breaker (ACB) 63 kA, 400 V, 2000 A
Protective elements :
• Excessive starting time and locked rotor (48-51LR)
• Over Current (50/51)
• Over Load (49)
• Phase imbalance (46)
• Under Voltage (27)
• Ground Fault (50N/51N)
Low Voltage System Protection
-
Incoming 400 V from Power Distribution Transformer
Feeder Protection Relay
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2022-08-30
Project Document No: T1-PP-000-ELE-STU-00003
Air Circuit Breaker (ACB) 63 kA, 400 V, 2000 A
Protective elements :
• Instantaneous / time delay current relay (ANSI 50/51)
• Earth Fault Relay (ANSI 50N/51N)
• Over voltage (ANSI 59)
-
Outgoing 400 V to Power Feeders
Molded Case Circuit Breaker (MCCB)
Protective elements:
• Instantaneous Over Current Protection (ANSI 50)
-
Outgoing 400 V to Electric Motor
Molded Case Circuit Breaker (MCCB)
Protective elements:
• Instantaneous Over Current Protection (ANSI 50)
REV. 1
Page 2 of 17
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
8.
2022-08-30
Project Document No: T1-PP-000-ELE-STU-00003
REV. 1
Page 2 of 17
METHODOLOGY AND CALCULATION CRITERIA
8.1 Study Case
The study is based on the data and parameter as performed by ETAP Power System Analysis
Software ver. 12.5.0C which has provided some characteristic curved used as parameter in this
project as follow:
•
•
•
•
•
•
Transformer thermal damage and inrush current curve
Cable thermal damage curve
Protection Device (Circuit Breaker, MCCB) curve
Motor Starting Curve (if any)
Thermal Overload relay Curve (if any)
Protective Relay Curve
For initial setting, the protection devices used are listed as below:
•
•
•
•
Circuit Breaker
ACB Relay
VCB Relay
Electronic Motor Protection Relay
Time grading between protective devices is determined with the following consideration:
•
•
•
Circuit Breaker Operating Time
Retardation Time
Safety Margin
: 80 ms
: 20 ms
: 100 ms
Therefore, minimum time grading is considered at 0.2 s to achieve acceptable breaker operating
time. In case time grading is not applied, current grading shall be concerned. In this study, time
grading for upstream and downstream of feeder and transformer are only applied for low set
overcurrent only, high set overcurrent setting is not considered within this stage.
Protection relays setting which are considered in this study is listed below,
•
•
49 – Thermal Overload Relay
50/51 – Instantaneous/Overcurrent Relay
Others required setting to be developed during detail design after relay/switchgear vendor
selected. The following list of protection setting and grading are basis consideration only. Detailed
relay coordination by considering equipment characteristic shall refer to the Relay Coordination
Curve attached in Appendix-xx and shall be updated after receiving Vendor data.
8.2 Protection for Line Differential
This setting is to protect overhead line cable. This setting should be defined as the minimum
pickup differential current to operate the element under the normal load conditions and steady
state CT error during no load condition. There are, however, conditions, which may result a
differential current even when there would be no fault. Therefore, it is important to take care of
these conditions while calculating this setting. Following conditions shall be considered:
Errors due to the CT Inaccuracy:
Ierror = 0.1 * 1 = 0.1 pu [10]
Cable Charging Currents :.
X1line_capacitive = DC resistance * length
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2022-08-30
Project Document No: T1-PP-000-ELE-STU-00003
REV. 1
Page 2 of 17
= 1/(2*3.14*50*0.143) *0.35 km
= 11.13 Ω
Since the capacitance is too small, the setting is not applicable.
Icharging
=(Vline-ground)/(X1line_capacitive)
= (86 KV)/11.13Ω
= 7.72 A (0.003 pu)
And since charging current is too small, it can be negligible.
Therefore, the pickup setting equation could be:
Pickupdifferential=Ierror+Itap_changer+SafetyMargin
In this case, Itap changer is 10% and assuming safety margin is 5%
Pickupdifferential=0,1+0,1+0,05 = 0,25pu
8.3 Protection for Overall Differential
Overall differential protection is required to protect big generator-transformer units. For this
particular application this maximum power corresponds to the following base currents on three
different voltage levels connected to the relay :
- At 150 kV :
Ifl = 281 A. This corresponds to 0,937 A on the secondary side 300/1 CT.
- At 15 kV :
Ifl = 2853 A. This corresponds to 0,71325 on the secondary side 4000/1 CT.
- At 15 kV :
Ifl = 1066 A. This corresponds to 1,6931 on the secondary side of 630/1 CT.
Above currents will be the base current for each side. Overall differential protection can be set
to minimum pickup 20%. All other settings for the operating characteristic can be left to default
values.
8.4 Protection for LV Feeder
Molded Case Circuit Breaker (MCCB) is used to protect outgoing 400 V Power Feeder. Feeder
protection to be provided by manufacturer to provide the following protection elements:
- 50/51 – Instantaneous/Time Delay Overcurrent (MCCB)
➢
➢
Overcurrent Setting: 110% x FLA
Instantaneous Setting: 1000% x FLA
8.5 Protection for LV Motor
Multifunction motor protection relay and Molded Case Circuit Breaker (MCCB) is used to protect
outgoing 400 V Motor. Minimum protection relay to be provided by manufacturer is specified as
follow:
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2022-08-30
Project Document No: T1-PP-000-ELE-STU-00003
REV. 1
Page 2 of 17
- 49 – Thermal Overload
➢
➢
➢
This function is used to protect motor against overload based on measurement of current
consumed. The protection gives a trip when the temperature reaches setting limit.
Thermal class selected is Class 10, by considering Lock Rotor Current is 6xFLA (to be
revisited after receiving vendor motor data
Current Setting: 110% x FLA
- 50/51 – Instantaneous/Time Delay Overcurrent (MCCB)
➢
➢
➢
➢
➢
This protection will be covered by MMC, to protect cable and motor from short circuit
current
Current setting of instantaneous overcurrent is mainly determined by the maximum short
circuit current and starting current of motor
Current Setting (with DOL Starter): 800%-1000% x FLA
Current Setting (with Soft Starter): 800%-1000% x FLA
Time Setting: 0.05 s (instant)
8.6 Protection for 6.3/0.4 kV Power Distribution Transformer
Multifunction feeder protection relay is used to protect transformer. Minimum protection relay to
be provided by manufacturer is specified as follow:
•
•
•
50 – Instantaneous Overcurrent Relay
51 – Time Inverse Overcurrent Relay
87T – Transformer Differential Relay
In this study, the basis coordination setting for this function is as follow:
Secondary Side (0.4 kV)
-
50 – Instantaneous Overcurrent
➢
➢
-
Current Setting: 300% x FLA (LV Side)
Time Delay: time graded 0.2 second from downstream protection.
51 – Time Inverse Overcurrent
➢
Current Setting: 110% x FLA (LV Side)
Primary Side (6.3 kV)
-
50 – Instantaneous Overcurrent
➢
➢
-
51 – Time Inverse Overcurrent
➢
-
Current Setting: 300%* x 110% x FLA (HV Side)
Time Delay: no time grading with downstream incomer required.
Current Setting: 110% x 110% x FLA (HV Side)
87T – Differential Transformer
➢
Pickup Setting: 20%
Note:
1.
* → Shall be above transformer inrush current value, to be updated during detailed
design
8.7 Protection for 15/6.3 kV Unit Auxiliary Transformer
Multifunction feeder protection relay is used to protect transformer. Minimum protection relay to
be provided by manufacturer is specified as follow:
•
•
50 – Instantaneous Overcurrent Relay
51 – Time Inverse Overcurrent Relay
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2022-08-30
Project Document No: T1-PP-000-ELE-STU-00003
REV. 1
Page 2 of 17
In this study, the basis coordination setting for this function is as follow:
Secondary Side (6.3 kV)
-
50 – Instantaneous Overcurrent
➢
➢
-
Current Setting: 300% x FLA (LV Side)
Time Delay: time graded 0.2 second from downstream protection.
51 – Time Inverse Overcurrent
➢
Current Setting: 110% x FLA (LV Side)
8.8 Protection for 150/15 kV Generator Transformer
Multifunction feeder protection relay is used to protect transformer. Minimum protection relay to
be provided by manufacturer is specified as follow:
•
•
•
50 – Instantaneous Overcurrent Relay
51 – Time Inverse Overcurrent Relay
87T – Differential Transformer Relay
In this study, the basis coordination setting for this function is as follow:
Primary Side (150 kV)
-
50 – Instantaneous Overcurrent
➢
➢
-
51 – Time Inverse Overcurrent
➢
-
Current Setting: 300%* x FLA (HV Side)
Time Delay: time grading with downstream incomer required.
Current Setting: 110% x FLA (HV Side)
87T – Differential Transformer
➢
Pickup Setting: 20%
Note:
1.
* → Shall be above transformer inrush current value, to be updated during detailed
design
8.9 Protection for Generator
Multifunction protection relay is used to protect generator. Minimum protection relay to be
provided by manufacturer is specified as follow:
•
•
•
50 – Instantaneous Overcurrent Relay
51 – Time Inverse Overcurrent Relay
87G – Generator Differential Relay
Within this study, only relay 50/51 are coordinated with the following setting:
-
50 – Instantaneous Overcurrent
➢
➢
-
51 – Time Inverse Overcurrent
➢
-
Current Setting: before generator steady state short circuit curve
Time Delay: time grading 0.2 second from GT & AUT protection.
Current Setting: 110% x FLA
87T – Differential Transformer
➢
Pickup Setting: 20%
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2022-08-30
8.10
Project Document No: T1-PP-000-ELE-STU-00003
REV. 1
Page 2 of 17
Protection for Emergency Diesel Generator (EGD)
Multifunction protection relay is used to protect generator. Minimum protection relay to be
provided by manufacturer is specified as follow:
•
50 – Instantaneous Overcurrent Relay
•
51 – Time Inverse Overcurrent Relay
Within this study, only relay 50/51 are coordinated with the following setting:
-
50 – Instantaneous Overcurrent
➢
➢
-
Current Setting: before generator steady state short circuit curve
Time Delay: time grading 0.2 second from downstream protection.
51 – Time Inverse Overcurrent
➢
Current Setting: 110% x FLA
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2022-08-30
8.11
Project Document No: T1-PP-000-ELE-STU-00003
REV. 1
Page 2 of 17
Study Case
1. Case 1 – Motor Type Load Relay Coordination on 0.4 kV Essential MCC Bus
Picture.1 – Coordination Relay Case – 1
•
•
•
•
For example, coordination relay for Jacking Oil Pump 1A motor with CB Incoming 0.4 kV
Essential MCC Bus
Coordination motor relay (Over Load Relay /Thermal Overload) with Incoming protection
relay (Over current Relay).
Fault from downstream.
Trip Sequence
Motor Protection
1
MCCB for Motor
2
Relay Protection for Incoming CB
3
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2022-08-30
Project Document No: T1-PP-000-ELE-STU-00003
REV. 1
Page 2 of 17
2. Case 2 – Feeder Type Load Relay Coordination on 0.4 kV Essential MCC Bus
Picture.2 – Coordination Relay Case – 2
•
•
•
•
For example, relay for feeder Generator Anti-Cond Heater with CB Incoming 0.4 kV
Essential MCC Bus
Coordination feeder protection relay (Include with CB) with Incoming protection relay
(Over current Relay).
Fault from downstream.
Trip Sequence
MCCB for Feeder
1
Relay Protection for Incoming CB
2
3. Case 3 – Motor Type Load Relay Coordination on 0.4 kV MCC Bus
Picture.3 – Coordination Relay Case – 3
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2022-08-30
•
•
•
•
Project Document No: T1-PP-000-ELE-STU-00003
REV. 1
Page 2 of 17
For example, coordination relay for motor Bottom Ash Shieving Equipment with CB
Incoming 0.4 kV MCC Bus
Coordination feeder motor relay (Over Load Relay /Thermal Overload) with Incoming
protection relay (Over current Relay).
Fault from downstream.
Trip Sequence
Motor Protection
1
MCCB for Motor
2
Relay Protection for Incoming CB
3
4. Case 4 – Feeder Type Load Relay Coordination on 0.4 kV MCC Bus
Picture.4 – Coordination Relay Case – 4
•
•
•
•
For example, coordination relay for feeder Fuel Feeding Line with CB Incoming 0.4 kV
MCC Bus
Coordination feeder protection relay (Include with CB) with Incoming protection relay
(Over current Relay).
Fault from downstream.
Trip Sequence
MCCB for Feeder
1
Relay Protection for Incoming CB
2
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2022-08-30
Project Document No: T1-PP-000-ELE-STU-00003
REV. 1
Page 2 of 17
5. Case 5 – Motor Type Load Relay Coordination on 0.4 kV SWGR Bus
Picture.5 – Coordination Relay Case – 5
•
•
•
•
For example, coordination relay for motor Vacuum Pump 1A with CB Incoming 0.4 kV
SWGR Bus
Coordination feeder motor relay (Over Load Relay /Thermal Overload) with Incoming
protection relay (Over current Relay).
Fault from downstream.
Trip Sequence
Motor Protection
1
MCCB for Motor
2
Relay Protection for Incoming CB
3
6. Case 6 – Feeder Type Load Relay Coordination on 0.4 kV SWGR Bus
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2022-08-30
Project Document No: T1-PP-000-ELE-STU-00003
REV. 1
Page 2 of 17
Picture.6 – Coordination Relay Case – 6
•
•
•
•
For example, coordination relay for feeder ESP Package – 1 with CB Incoming 0.4 kV
MCC SWGR
Coordination feeder protection relay (Include with CB) with Incoming protection relay
(Over current Relay).
Fault from downstream.
Trip Sequence
MCCB for Feeder
1
Relay Protection for Incoming CB
2
7. Case 7 – Motor Type Load Relay Coordination on MV Switchgear Bus
Picture.7 – Coordination Relay Case – 7
•
•
•
•
For example, coordination relay for Primary Air Fan 1A motor with CB Incoming 6.3 kV
MV Switchgear
Coordination feeder motor relay (Over Load Relay /Thermal Overload) with Incoming
protection relay (Over current Relay).
Fault from downstream.
Trip Sequence
Motor Protection
1
MCCB for Motor
2
Relay Protection for Incoming CB
3
8. Case 8 – Power Distribution Transformer Protection Coordination
Picture.8 – Coordination Relay Case – 8
•
For example, coordination relay for CB Outgoing 6.3 kV MVSG-1A with CB Incoming 0.4
kV LVSG-1A.
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2022-08-30
•
•
•
Project Document No: T1-PP-000-ELE-STU-00003
REV. 1
Page 2 of 17
Coordination Outgoing protection relay (Over Current Relay) with Incoming feeder
protection relay (Over current Relay).
Fault from downstream.
Trip Sequence
Relay Protection for Incoming CB
1
Relay Protection for Outgoing CB
2
9. Case 9 – MV Switchgear Protection Coordination
Picture.9 – Coordination Relay Case – 9
•
•
•
•
For example, coordination relay for CB Outgoing 6.3 kV MVSG-1A with CB Incoming 6.3
kV MVSG-1A.
Coordination Outgoing protection relay (Over Current Relay) with Incoming feeder
protection relay (Over current Relay).
Fault from downstream.
Trip Sequence
Relay Protection for Incoming CB
1
Relay Protection for Outgoing CB
2
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2022-08-30
Project Document No: T1-PP-000-ELE-STU-00003
REV. 1
Page 2 of 17
10. Case 10 – Interconnecting Cable (MVSG & MVSG Common) Protection Coordination
Picture.10 – Coordination Relay Case – 10
•
•
•
•
For example, coordination relay for CB Incoming 6.3 kV MVSG – 12A Common with CB
Incoming 6.3 kV MVSG-1A.
Coordination Incoming protection relay (Over Current Relay) with Incoming feeder
protection relay (Over current Relay).
Fault from downstream.
Trip Sequence
Relay Protection for Incoming CB (MVSG-12A Common)
1
Relay Protection for Incoming CB (MVSG-1A)
2
11. Case 11 – Feeder Type Load Relay Coordination on MV Switchgear Common Bus
Picture.11 – Coordination Relay Case – 11
•
•
•
•
For example, coordination relay for CSU Trans. T001 Feeder with CB Incoming 6.3 kV
MVSG-12A Common Bus.
Coordination Incoming protection relay (Over Current Relay) with Incoming feeder
protection relay (Over current Relay).
Fault from downstream.
Trip Sequence
Relay Protection for outgoing Feeder CSU Trans. T1001
1
Relay Protection for incoming CB (MVSG-12A Common)
2
12. Case 12 – Generator and UAT Protection Coordination
Picture.12 – Coordination Relay Case – 12
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2022-08-30
•
•
•
•
Project Document No: T1-PP-000-ELE-STU-00003
REV. 1
Page 2 of 17
Coordination relay for CB Incoming 15 kV Bus (Generator – 1) with CB Incoming 6.3 kV
MVSG-1A.
Coordination Incoming protection relay (Over Current Relay) with Incoming feeder
protection relay (Over current Relay).
Fault from downstream.
Trip Sequence
Relay Protection for Incoming CB (UAT)
1
Relay Protection for Incoming CB (Generator)
2
13. Case 13 – Generator and GT Protection Coordination
Picture.13 – Coordination Relay Case – 13
•
•
•
•
9.
Coordination relay for CB Incoming 15 kV Bus (Generator – 1) with CB Outgoing 150 kV
Bus (HV Side GT(Generator Transformer)).
Coordination Incoming protection relay (Over Current Relay) with Outgoing feeder
protection relay (Over current Relay).
Fault from downstream.
Trip Sequence
Relay Protection for Incoming CB (Generator)
1
Relay Protection for Outgoing CB (GT)
2
CONCLUSION
Based on these above calculations, the relays setting should be followed as attachment.
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2020-11-12
Project Document No: T1-PP-000-ELE-STU-00003
ATTACHMENT 1
SINGLE LINE DIAGRAM
REV.
0
One-Line Diagram - OLV1 (Edit Mode)
150 kV EXISTING SWITCHYARD
GT-1
GT-2
CBGRID5
CBGRID6
CBGRID3
CBGRID4
SWITCHYARD
150 kV
SWITCHYARD
SWITCHYARD
CBHV1
CBGRID1
CBGRID2
CBHV2
GT-1
73 MVA
GT-2
73 MVA
BUS-100
15 kV
BUS-200
15 kV
BusDuct3
BusDuct2
BusDuct7
BusDuct6
GCB-1
GCB-2
UAT-1A
16 MVA
UAT-2A
16 MVA
BusDuct1
BusDuct5
BusDuct15
Gen1
63 MW
CB1100
MVSG-1A
6.3 kV
CB10-1
CB10-11
CB1104
CB1105
CB1106
CB1110
CB1111
CB1112
CB1113
CB1114
CB1115
CB1116
CB1002
CB1003
CB1004
CB1006
CB1007
CB1008
CB1009
Cable0MV2
Cable0MV3
Cable0MV4
Cable0MV6
Cable0MV7
Cable0MV8
Cable0MV9
Bus0MV2
Bus0MV3
Bus2MV1
CB1212
CB1213
CB0LV5
CB0LV10
CB0LV11
CB0LV12
CB0LV13
CB0LV20
CB0LV21
Interface Busbar 2B
CB2LV2
Open
LVSG-2A
0.4 kV
LVSG-2B
0.4 kV
CB0LV22
CB0LV23
CB0LV24
CB0LV18
CB0LV19
CB2LV3
CB0LV6
CB2LV4
CB2LV5
CB2LV6
Cable2LV2
Cable2LV3
CB2LV11
CB2LV13
CB2LV7
CB2LV12
CBCHLV2
Cable1LV1
Cable1LV2
Bus1LV1
Bus1LV2
Cable1LV3
Cable0LV2
Cable0LV4
Bus0LV2
Bus0LV9
Cable0LV6
Bus0LV10
Cable0LV7
Bus0LV4
Cable0LV14
0.4 kV
LV SWI MCC
Cable0LV15
Cable0LV16
Bus0LV12
Cable0LV18
Bus0LV14
Cable0LV12
Bus0LV15
Bus0LV6
0.4 kV
LV ESP 2 MCC
NET_LV-2 ESS MCC
Open
CB34
CB39
Open
Cable17
CB36
CB45
Open
Cable28
CB41
Open
Cable30
CB47
CB2LV10
Open
HP AIR FAN 3 - 2
149 kW
CB2LV9
Bus2LV4
HP AIR FAN 2 - 2
149 kW
CB2LV8
Open
Bus2LV2
Cable2LV4
HP AIR FAN 1 - 2
149 kW
CB0LV9
Bus2LV1
ESP PACKAGE 2
282.4 kVA
CB33
LVSG EDG
0.4 kV
LV-2 ESS MCC
LV-12 ESS COMMON MCC
LV-1 ESS MCC
Project File: Timor1-CFSPP-2x50MW
0.4 kV
LV WTP-WWTP MCBCus0LV3
NET_LV-2AB MCC
EDG
1600 kW
Aug 28, 2022
Cable2LV1
Cable30
NET_LV-12AB COMMON MCC
EDG
10:15:33
Cable0LV3
NET_LV CH MCC
Cable28
NET_LV-1AB MCC
Cable0LV13
WTP & WWTP
276.5 kVA
RF at TH
110 kVA
TRANS + SERV AIR 3
171.6 kVA
TRANS + SERV AIR 2
171.6 kVA
TRANS + SERV AIR 1
171.6 kVA
NET_LV-12 ESS COMMON MCC
Cable17
Cable0LV17
Bus0LV13
DB LP
411.8 kVA
SWI & CHLOR
77.07 kVA
HVAC at STG
110 kVA
AIR COMP 3
117.6 kVA
AIR COMP 2
117.6 kVA
AIR COMP 1
CB0LV8
CB0LV7
Cable0LV5
Bus0LV8
117.6 kVA
CB1LV10 Open
HP AIR FAN 3
149 kW
HP AIR FAN 2
149 kW
NET_LV-1 ESS MCC
page 1
Bus0LV1
Bus1LV4
HP AIR FAN 1
149 kW
ESP PACKAGE 1
CB1LV9
Cable0LV1
Cable1LV4
0.4 kV
LV ESP 1 MCC
282.4 kVA
CB1LV8
Bus1
0.4 kV
CB1216
CW Pump 2B
580 kW
CB0LV4
CB1215
CW Pump 2A
580 kW
CB1LV12
CB1214
CE Pump 2B
160 kW
LV-CH MCC
0.4 kV
CB0LV3
CB1LV7
CE Pump 2A
160 kW
BFW Pump 2C
950 kW
Interface Busbar 2A
CB2LV1
LVSG-12B COMMON
0.4 kV
CB1211
BFW Pump 2B
950 kW
BFW Pump 2A
950 kW
ID FAN 2B
680 kW
CB1LV13
ID FAN 2A
CB1LV11
CB1210
PDC-CH2
Open
LVSG-12A COMMON
0.4 kV
CB1LV3
CB1LV6
CB1206
CBCHLV4
Open
CB0LV2
CB1205
680 kW
PDC-CH1
CB1204
CB1218
Bus2MV2
LV-CH MCC
CBCHLV1
CB1203
SECONDARY AIR FAN 2B
250 kW
Interface Busbar CH-2
CB1202
SECONDARY AIR FAN 2A
250 kW
PDC-2A
1.6 MVA
PDC-CH2
0.8 MVA
CB1201
PRIMARY AIR FAN 2B
650 kW
CB0LV1
Open
Gen2
63 MW
CB1200
PRIMARY AIR FAN 2A
650 kW
TRANS/RECT B
235.3 kVA
LV-CH MCC
SHIP UNLOADER B
563.8 kVA
PDC-CH1
0.8 MVA
Open
CB1217
Bus0MV10
PDC-12B
2 MVA
Interface Busbar CH-1
CB1011
Cable0MV11
Bus0MV8
Bus0MV6
Interface Busbar 12B
Interface Busbar 12A
CB1LV2
LVSG-1B
0.4 kV
CB1LV5
Bus0MV7
STACKER RECLAIMER
574.7 kVA
PDC-1B
1.6 MVA
TRANS/RECT A
235.3 kVA
PDC-12A
2 MVA
CB10-2
MVSG-2A
6.3 kV
Interface Busbar 1B
CB1LV1
LVSG-1A
0.4 kV
CB1LV4
Bus0MV4
Bus0MV5
SHIP UNLOADER A
563.8 kVA
CW Pump 1B
580 kW
Interface Busbar 1A
CW Pump 1A
580 kW
CE Pump 1B
160 kW
CE Pump 1A
160 kW
BFW Pump 1C
950 kW
BFW Pump 1B
950 kW
BFW Pump 1A
950 kW
ID FAN 1B
680 kW
ID FAN 1A
680 kW
SECONDARY AIR FAN 1B
250 kW
SECONDARY AIR FAN 1A
250 kW
PRIMARY AIR FAN 1B
650 kW
PRIMARY AIR FAN 1A
650 kW
PDC-1A
1.6 MVA
CB1001
Cable0MV1
Bus0MV1
Bus1MV2
Open
Cable33
CB1103
CB10-12
MVSG-12B COMMON
6.3 kV
Cable2MV17
CB1102
CableMV18
CableMV17
6
.3sk1V
Bu
MV1
CB1118
CB1101
Bus2
6.3 kV
BusDuct8
CB10-10
MVSG-12A COMMON
6.3 kV
Open
CB1117
BusDuct16
BusDuct9
BusDuct4
PDC-2B
1.6 MVA
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2020-06-26
Project Document No: T1-PP-000-ELE-STU-00003
ATTACHMENT 2
TABEL SETTING FOR PROTECTION RELAY
REV.
0
Table A
VT Ratio (V)
Circuit Breaker Tag
Incoming 150 kV to GT (HV)
Panel Location
CB 40 kA, 150 kV, 300A
Voltage
150kV
Device
7UT86
150 kV
Overall Incoming, GT, UAT
-
15 kV
REX640
15 kV
Incoming 150 kV to GT (LV)
Outgoing 15 kV to UAT (HV)
GCB 50 kA, 15 kV, 4000 A
VCB 40 kA, 15 kV, 630 A
15 kV
15kV
RET615
7UT82
Prim.
150000
CT Ratio (A)
Sec
100
Prim.
300
150000
100
300
15000
100
4000
15000
100
630
15000
15000
100
100
630
630
Existing Setting
Protection
Sec
Incoming 15 kV from Generator
VCB 25 kA, 15 kV, 1600 A
VCB 50 kA, 15 kV, 4000A
6,3kV
15kV
7UT82
REX640
6300
15000
100
100
Set Point
(A, V, Hz)
Time Dial
(s)
Remarks
87L
Definite Time
25%xIpckup
0s
Differential Transformer Protection
87T
Definite Time
20%xIpckp
0s
Restricted Earth Fault
64 REF
Definite Time
0.05 A
1s
Time Delay Overcurrent
50
IEC - SIT
Table
Instataneous Overcurrent
51
Definite Time
Table
50N
Definite Time
Table
Instataneous Ground Overcurrent
51N
Definite Time
Transformer Over Winding Temperature
49 WT
Definite Time
90%xTn
1s
Transformer Over Oil Temperature
49 OT
Definite Time
90%xTn
1s
Transformer Gas Protection/Buchholz
63
OFF
OFF
OFF
Transformer Over Flux Protection
24
Definite Time
115% V/f
1s
Definite Time
20%xIpckup
0.2 s
0.05 A
800 ms
1 Time Delay Ground Overcurrent
1
1 Overall Differential Protection
Table
opt. via CO
87O
1
Restricted Earth Fault
64 REF
Definite Time
Time Delay Overcurrent
50
IEC - SIT
Table
1 Instataneous Overcurrent
51
Definite Time
Table
Time Delay Ground Overcurrent
50N
Definite Time
Table
Instataneous Ground Overcurrent
51N
Definite Time
Differential Transformer Protection
87 UAT
Definite Time
20%xIpckp
0s
Restricted Earth Fault
64 REF
Definite Time
0.05 A
1s
Time Delay Overcurrent
50
IEC - SIT
Table
Instataneous Overcurrent
51
Definite Time
Table
50N
Definite Time
Table
Instataneous Ground Overcurrent
51N
Definite Time
Transformer Over Winding Temperature
49 WT
Definite Time
90%xTn
1s
Transformer Over Oil Temperature
49 OT
Definite Time
90%xTn
1s
Transformer Gas Protection/Buchholz
63
OFF
OFF
OFF
SBEF
Definite Time
0.02 A
0s
64 REF
Definite Time
0.05 A
1s
50/51
-
-
-
Table
Earth Fault
50N/51N
-
-
-
Table
Generator 100% Stator Earth Fault
Protection
59G
Generator Differential Protection
87G
Definite Time
10%xIpckp
0s
Generator Negative Phase Sequence
Protection
46
IEC - SIT
0,05 A
2s
Generator Loss of Excitation Protection
40
IEC - SIT
0,66 ohm
50 ms
Generator Over-Excitation (V/Hz) Protection
24
Definite Time
120% V/Hz
6s
Generator Reverse Power Protection
32
Definite Time
8Vph
30 s
Generator Overvoltage Protection
59
Definite Time
110Vph
1s
Generator Under voltage Protection
27
Definite Time
80Vph
50 ms
Generator Voltage Controlled Over current
relay
51V
Generator Rotor Earth Fault
64F
Impedance Protection
21
Voltage Balance Protection
60
Definite Time
80%Unp
Overfrequency
81H
Definite Time
51,5 Hz
2s
Underfrequency
81L
Definite Time
48,5 Hz
2s
Generator Out of Step Protection
78
Generator Stator Thermal Protection
49
IEC - LIT
1,05 A
1s
Time Delay Overcurrent
50
1 Time Delay Ground Overcurrent
1600
2 Standby Earth Fault for NGR
1600
1 Over Current
4000
Curve
Line Differential Protection
Restricted Earth Fault
Outgoing 15kV to UAT (LV)
ANSI Code
1
Table
Table
opt. via CO
OFF
OFF
OFF
OFF
Incoming 6.3 kV from UAT
VCB 25 kA, 6.3 kV, 1600 A
6.3 kV
7UT82
6300
100
1600
1600
Outgoing 6.3 kV to Electric Motor
Incoming 400 V from Power Distribution
Transformer
ACB 6.3 kA, 400 V, 1600 A
Air Circuit Breaker (ACB) 65 kA, 400 V, 2500 A
6.3 kV
400 V
7SJ80
7SJ80
400
400
100
100
2500
2500
Instataneous Overcurrent
51
Time Delay Ground Overcurrent
50N
Instataneous Ground Overcurrent
51N
Differential Transformer Protection
87 UAT
Restricted Earth Fault
64 REF
Over Current
50/51
-
-
-
Table
50N/51N
-
-
-
Table
Transformer Over Winding Temperature
49 WT
Definite Time
90%xTn
1s
Transformer Over Oil Temperature
49 OT
Definite Time
90%xTn
1s
Transformer Gas Protection/Buchholz
63
OFF
OFF
OFF
opt. via CO
SBEF
Definite Time
0,02 A
1 Earth Fault
2 Standby Earth Fault for NGR
1
Definite Time
OFF
Excessive starting time and locked rotor
48-51LR
Over Current
50/51
-
-
-
Table
Over Load
49
IEC - LIT
1,05 A
500 ms
Table
Phase imbalance
46
Define Time
0,2 A
2s
Under Voltage
27
Definite Time
80 Vph
2s
Ground Fault
50N/51N
-
-
-
Time Delay Phase Overcurrent
51
Table
Instantaneous Phase Overcurrent
50
Table
51N
Table
1 Time Delay Ground Overcurrent
Instantaneous Ground Overcurrent
50N
Over voltage
59
Table
Table
Definite Time
110 Vph
1s
Outgoing 400 V to Power Feeders
Molded Case Circuit Breaker (MCCB)
400 V
MCCB
400
100
2500
1 Instantaneous Over Current Protection
50
Table
Outgoing 400 V to Electric Motor
Molded Case Circuit Breaker (MCCB)
400 V
MCCB
400
100
2500
1 Instantaneous Over Current Protection
50
Table
FLA
Isc
MF
Full Load Ampere
Short Circuit Current or Breaking Capacity of Breaker
Margin Factor
150 kV
No
Tag No.
Description
Protection-Type
CT Ratio
FLA (A)
Isc max
1
2
11BAT01GT001
12BAT01GT001
GT - 1
GT - 2
SIEMENS 7SJ80
SIEMENS 7SJ80
300/1
300/1
281
281
40
40
No
Tag No
Protection-Type
CT Ratio
Ifl
ISC Max
Low Set O/C
MF x FLA
(A)
309,1000
309,1000
High Set O/C
Pick-Up
Type
Range
TMS
Inst
Type
Range
Td (s)
1,0
1,0
IEC - Inverse
IEC - Inverse
0.1-4 x CT Sec
0.3-5 x CT Sec
0,10
0,10
2
2
Definite
Definite
0.5-35 x CT Sec
0.5-35 x CT Sec
0,20
0,20
Note
15 kV IINCOMING MV SWITCHGEAR
Description
Low Set O/C
High Set O/C
Ifl x MF
Pick-Up
Type
Range
TMS
Inst
Type
Range
Note
Td (s)
1
11BAY01BR001
Gen-1
SIEMENS 7SJ80
4000/1
2853
40
3138,3
0,8
IEC - LI
0.3-5 x CT Sec
0,20
5,3
Definite
0.5-35 x CT Sec
0,40
2
12BAY01BR001
Gen-2
SIEMENS 7SJ80
4000/1
2853
40
3138,3
0,8
IEC - LI
0.3-5 x CT Sec
0,20
5,3
Definite
0.5-35 x CT Sec
0,40
Tag No.
Description
Protection-Type
CT Rated /
MCCB Capacity
FLA (A)
0.4 kV OUTGOING LV SWITCHGEAR
No
ISC Max
(kA)
Low Set O/C Relay or Thermal Trip MCCB
High Set O/C Relay or Magnetic
Trip MCCB
MF x FLA
(A)
Pick-Up
Type
TMS
Pick-up
Type
TD (s)
MVSG-1A
1
11BBA01BR001
UAT-1
Siemens 7UT82
1600/1
1612,9
25
1774,21
1,1
IEC - LI
0,70
3,0
Definite
0,40
12BBA01BR001
UAT-2
Siemens 7UT82
1600/1
1612,9
25
1774,21
1,1
IEC - LI
0,70
3,0
Definite
0,40
MVSG-2A
2
Note
0.4 kV OUTGOING LV SWITCHGEAR
No
Tag No.
Discription
Protection-Type
CT Rated / MCCB
Capacity
FLA (A)
ISC Max
(kA)
Low Set O/C Relay or Thermal Trip MCCB
High Set O/C Relay or Magnetic
Trip MCCB
MF x FLA
(A)
Pick-Up
Type
TMS
Pick-up
Type
TD (s)
MVSG-1A
1
11BFT01GT001
PDC-1A
Siemens 7UT82
400/1
108,8
25
131,62
0,3
IEC - LI
0,70
0,9
Definite
0,40
2
11HLB11AN101-M01
Primary Air Fan 1A
Siemens 7SJ80
200/1
72,9
25
80,20
0,4
IEC - LI
0,70
2,9
Definite
0,20
3
11HLB12AN101-M01
Primary Air Fan 1B
Siemens 7SJ80
200/1
72,9
25
80,20
0,4
IEC - LI
0,70
2,9
Definite
0,20
4
11HLB21AN101-M01
Secondary Air Fan 1A
Siemens 7SJ80
100/1
28,5
25
31,37
0,3
IEC - LI
0,70
1,1
Definite
0,20
5
11HLB22AN101-M01
Secondary Air Fan 1B
Siemens 7SJ80
100/1
28,5
25
31,37
0,3
IEC - LI
0,70
1,1
Definite
0,20
6
11HNC10AN201-M01
Induced Draft Fan 1A
Siemens 7SJ80
200/1
77,7
25
85,45
0,4
IEC - LI
0,70
3,1
Definite
0,20
7
11HNC20AN201-M01
Induced Draft Fan 1B
Siemens 7SJ80
200/1
77,7
25
85,45
0,4
IEC - LI
0,70
3,1
Definite
0,20
8
11LAC11AP001-M01
Boiler Feed Water Pump 1A
Siemens 7SJ80
200/1
100,3
25
110,31
0,6
IEC - LI
0,70
4,0
Definite
0,20
9
11LAC12AP001-M01
Boiler Feed Water Pump 1B
Siemens 7SJ80
200/1
100,3
25
110,31
0,6
IEC - LI
0,70
4,0
Definite
0,20
10
11LAC13AP001-M01
Boiler Feed Water Pump 1C
Siemens 7SJ80
200/1
100,3
25
110,31
0,6
IEC - LI
0,70
4,0
Definite
0,20
11
11LCB11AP001-M01
Condensated Extraction Pump 1A
Siemens 7SJ80
100/1
18,3
25
20,14
0,2
IEC - LI
0,70
0,7
Definite
0,20
12
11LCB12AP001-M01
Condensated Extraction Pump 1B
Siemens 7SJ80
100/1
18,3
25
20,14
0,2
IEC - LI
0,70
0,7
Definite
0,20
13
11PAC11AP101-M01
Cooling Water Pump (CWP) A
Siemens 7SJ80
200/1
69,6
25
76,53
0,4
IEC - LI
0,70
2,8
Definite
0,20
14
11PAC12AP101-M01
Cooling Water Pump (CWP) B
Siemens 7SJ80
200/1
69,6
25
76,53
0,4
IEC - LI
0,70
2,8
Definite
0,20
15
11BFT02GT001
PDC-1B
Siemens 7UT82
400/1
108,8
25
131,62
0,3
IEC - LI
0,70
0,9
Definite
0,40
MVSG-2A
16
12BFT01GT001
PDC-2A
Siemens 7UT82
400/1
108,8
25
131,62
0,3
IEC - LI
0,70
0,9
Definite
0,40
17
12HLB11AN101-M01
Primary Air Fan 1A
Siemens 7SJ80
200/1
72,9
25
80,20
0,4
IEC - LI
0,70
2,9
Definite
0,20
18
12HLB12AN101-M01
Primary Air Fan 1B
Siemens 7SJ80
200/1
72,9
25
80,20
0,4
IEC - LI
0,70
2,9
Definite
0,20
19
12HLB21AN101-M01
Secondary Air Fan 1A
Siemens 7SJ80
100/1
28,5
25
31,37
0,3
IEC - LI
0,70
1,1
Definite
0,20
20
12HLB22AN101-M01
Secondary Air Fan 1B
Siemens 7SJ80
100/1
28,5
25
31,37
0,3
IEC - LI
0,70
1,1
Definite
0,20
21
12HNC10AN201-M01
Induced Draft Fan 1A
Siemens 7SJ80
200/1
77,7
25
85,45
0,4
IEC - LI
0,70
3,1
Definite
0,20
22
12HNC20AN201-M01
Induced Draft Fan 1B
Siemens 7SJ80
200/1
77,7
25
85,45
0,4
IEC - LI
0,70
3,1
Definite
0,20
23
12LAC11AP001-M01
Boiler Feed Water Pump 1A
Siemens 7SJ80
200/1
100,3
25
110,31
0,6
IEC - LI
0,70
4,0
Definite
0,20
24
12LAC12AP001-M01
Boiler Feed Water Pump 1B
Siemens 7SJ80
200/1
100,3
25
110,31
0,6
IEC - LI
0,70
4,0
Definite
0,20
25
12LAC13AP001-M01
Boiler Feed Water Pump 1C
Siemens 7SJ80
200/1
100,3
25
110,31
0,6
IEC - LI
0,70
4,0
Definite
0,20
26
12LCB11AP001-M01
Condensated Extraction Pump 1A
Siemens 7SJ80
100/1
18,3
25
20,14
0,2
IEC - LI
0,70
0,7
Definite
0,20
27
12LCB12AP001-M01
Condensated Extraction Pump 1B
Siemens 7SJ80
100/1
18,3
25
20,14
0,2
IEC - LI
0,70
0,7
Definite
0,20
28
12PAC11AP101-M01
Cooling Water Pump (CWP) A
Siemens 7SJ80
200/1
69,6
25
76,53
0,4
IEC - LI
0,70
2,8
Definite
0,20
29
12PAC12AP101-M01
Cooling Water Pump (CWP) B
Siemens 7SJ80
200/1
69,6
25
76,53
0,4
IEC - LI
0,70
2,8
Definite
0,20
30
12BFT02GT001
PDC-2B
Siemens 7UT82
400/1
108,8
25
131,62
0,3
IEC - LI
0,70
0,9
Definite
0,40
PDC-12A
Siemens 7UT82
400/1
141,6
25
171,33
0,4
IEC - LI
0,70
1,2
Definite
0,40
MVSG-12A COMMON
31
10BBB01GS001
32
10EAA1112AF001
CSU Transformer T001
Siemens 7SJ80
400/1
56,6
25
62,30
0,2
IEC - LI
0,70
0,4
Definite
0,20
33
10BFT02GT001
PDC-CH1
Siemens 7SJ80
400/1
68,3
25
82,63
0,2
IEC - LI
0,70
0,6
Definite
0,40
34
11GH302A
Stepdown transformer for rectifier transformer of electrolyser A
Siemens 7SJ80
400/1
24,0
25
26,35
0,1
IEC - LI
0,70
0,2
Definite
0,20
MVSG-12B COMMON
35
10BFT01GT002
PDC-12B
Siemens 7SJ80
400/1
141,6
25
171,33
0,4
IEC - LI
0,70
1,2
Definite
0,20
36
10BFT02GT002
PDC-CH2
Siemens 7SJ80
400/1
68,3
25
82,63
0,2
IEC - LI
0,70
0,6
Definite
0,20
37
10EAA1112AF001
CSU Transformer T201
Siemens 7SJ80
400/1
56,6
25
62,30
0,2
IEC - LI
0,70
0,4
Definite
0,20
38
11GH302B
Stepdown transformer for rectifier transformer of electrolyser B
Siemens 7SJ80
400/1
25,5
25
28,00
0,1
IEC - LI
0,70
0,2
Definite
0,20
39
10EAF10AF001
Stacker Reclaimer
Siemens 7SJ80
400/1
48,5
25
53,34
0,1
IEC - LI
0,70
0,4
Definite
0,20
Note
0.4 kV OUTGOING LV SWITCHGEAR
No
Tag No.
Discription
Protection-Type
CT Rated / MCCB
Capacity
FLA (A)
ISC Max
(kA)
Overload Relay Setting
(49)
Low Set O/C Relay or Thermal Trip MCCB
MF x FLA (A)
Class
MF x FLA
(A)
Pick-Up
Type
TMS
High Set O/C Relay or Magnetic
Trip MCCB
Pick-up
Type
TD (s)
1
IN-LVSG-1A from PDC-1A
Siemens 7UT82
2500/1
1713,2
40
-
-
1884,51
0,8
IEC - LI
0,70
2,1
Definite
0,40
2
IN-LVSG-1B from PDC-1B
Siemens 7UT82
2500/1
1713,2
63
-
-
1884,51
0,8
IEC - LI
0,70
2,1
Definite
0,40
3
IN-LVSG-2A from PDC-2A
Siemens 7UT82
2500/1
1713,2
63
-
-
1884,51
0,8
IEC - LI
0,70
2,1
Definite
0,40
4
IN-LVSG-2B from PDC-2B
Siemens 7UT82
2500/1
1713,2
63
-
-
1884,51
0,8
IEC - LI
0,70
2,1
Definite
0,40
5
IN-LVSG-12A from PDC-12A
Siemens 7UT82
3000/1
2230,1
63
-
-
2453,14
0,8
IEC - LI
0,70
2,2
Definite
0,40
6
IN-LVSG-12B from PDC-12B
Siemens 7UT82
3000/1
2230,1
63
-
-
2453,14
0,8
IEC - LI
0,70
2,2
Definite
0,40
7
IN-LV-CH MCC from PDC-CH1
Siemens 7UT82
1250/1
1075,5
40
-
-
1183,05
0,9
IEC - LI
0,70
2,6
Definite
0,40
8
IN-LV-CH MCC from PDC-CH2
Siemens 7UT82
1250/1
1075,5
40
-
-
1183,05
0,9
IEC - LI
0,70
2,6
Definite
0,40
Note
0.4 kV OUTGOING LV SWITCHGEAR
No
Tag No.
Discription
Protection-Type
CT Rated / MCCB
Capacity
FLA (A)
ISC Max
(kA)
Overload Relay Setting
(49)
Low Set O/C Relay or Thermal Trip MCCB
High Set O/C Relay or Magnetic
Trip MCCB
MF x FLA (A)
Class
MF x FLA
(A)
Pick-Up
Type
TMS
Pick-up
Type
TD (s)
LVSG-1A
1
11HHM01AN601-M01
HP Air Fan 1
Siemens 7SJ80
400/5
270,2
63
297,21
10
297,21
3,7
IEC - LI
0,02
23,6
Definite
0,20
2
11BJA01GS001
ESP Package Unit-1
Siemens 7SJ80
800/5
654,4
63
-
-
719,85
4,5
IEC - LI
0,70
28,6
Definite
0,20
3
11BMA01GS001
0.4kV ESS Unit-1 MCC
Siemens 7SJ80
630/5
388,6
63
-
-
427,43
3,4
IEC - LI
0,70
21,6
Definite
0,20
4
11BFA02GS001
0.4kV Unit-1 MCC
Siemens 7SJ80
630/5
461,9
63
-
-
508,13
4,0
IEC - LI
0,70
25,7
Definite
0,20
10
297,21
3,7
IEC - LI
0,02
23,6
Definite
0,20
5
11HHM02AN601-M01
HP Air Fan 2
Siemens 7SJ80
400/5
270,2
63
297,21
LVSG-1B
6
11BFA02GS001
0.4kV Unit-1 MCC
Siemens 7SJ80
630/5
461,9
63
-
-
508,13
4,0
IEC - LI
0,70
25,7
Definite
0,20
7
11HHM03AN601-M01
HP Air Fan 3
Siemens 7SJ80
400/5
270,2
63
297,21
10
297,21
3,7
IEC - LI
0,02
23,6
Definite
0,20
LVSG-2A
8
12HHM01AN601-M01
HP Air Fan 1
Siemens 7SJ80
400/5
270,2
63
297,21
10
297,21
3,7
IEC - LI
0,02
23,6
Definite
0,20
9
12BJA01GS001
ESP Package Unit-2
Siemens 7SJ80
800/5
654,4
63
-
-
719,85
4,5
IEC - LI
0,70
28,6
Definite
0,20
10
12BMA01GS001
0.4kV ESS Unit-2 MCC
Siemens 7SJ80
630/5
388,6
63
-
-
427,43
3,4
IEC - LI
0,70
21,6
Definite
0,20
11
12BFA02GS001
0.4kV Unit-2 MCC
Siemens 7SJ80
630/5
461,9
63
-
-
508,13
4,0
IEC - LI
0,70
25,7
Definite
0,20
12
12HHM02AN601-M01
HP Air Fan 2
Siemens 7SJ80
400/5
270,2
63
297,21
10
297,21
3,7
IEC - LI
0,02
23,6
Definite
0,20
0,20
LVSG-2B
13
12BFA02GS001
0.4kV Unit-2 MCC
Siemens 7SJ80
630/5
461,9
63
-
-
508,13
4,0
IEC - LI
0,70
25,7
Definite
14
12HHM03AN601-M01
HP Air Fan 3
Siemens 7SJ80
400/5
270,2
63
297,21
10
297,21
3,7
IEC - LI
0,02
23,6
Definite
0,20
MCCB
250
190,9
63
-
-
210,01
1,0
FIXED
FIXED
5,0
FIXED
FIXED
LVSG-12A
15
10QEA60AN701
Air Compressor #3
16
10QEA70AN701
Air Compressor #2
17
10QEA80AN701
Air Compressor #1
18
19
10BFA01GS001
250
190,9
63
-
-
210,01
1,0
FIXED
FIXED
FIXED
FIXED
MCCB
250
190,9
63
-
-
210,01
1,0
FIXED
FIXED
5,0
FIXED
FIXED
0.4kV ESS COM-12AB MCC
Siemens 7SJ80
MCCB
630/5
408,6
63
-
-
449,41
3,6
IEC - LI
0,70
22,7
5,0
Definite
0,20
0.4kV COM-12AB MCC
Siemens 7SJ80
630/5
457,3
63
-
-
503,07
4,0
IEC - LI
0,70
25,4
Definite
0,20
MCCB
300
253,0
63
278,30
10
278,30
1,0
FIXED
FIXED
8,0
FIXED
FIXED
20
Electrical Pump
21
HVAC Switchgear Room
MCCB
250
198,5
63
-
-
218,31
1,0
FIXED
FIXED
5,0
FIXED
FIXED
22
SWI & Chlorination Package
Siemens 7SJ80
250/5
247,3
63
-
-
272,00
5,4
IEC - LI
0,70
34,6
Definite
0,20
0.4kV COM-12AB MCC
LVSG-12B
23
Siemens 7SJ80
630/5
457,3
63
-
-
503,07
4,0
IEC - LI
0,70
25,4
Definite
0,20
24
Air Compressor #1
MCCB
250
190,9
63
-
-
210,01
1,0
FIXED
FIXED
5,0
FIXED
FIXED
25
10BFA02GS001
Air Compressor #2
MCCB
250
190,9
63
-
-
210,01
1,0
FIXED
FIXED
5,0
FIXED
FIXED
26
Air Compressor #3
MCCB
250
190,9
63
-
-
210,01
1,0
FIXED
FIXED
5,0
FIXED
FIXED
27
WTP & WWTP Package
Siemens 7SJ80
630/5
480,7
63
-
-
528,74
4,2
IEC - LI
0,70
26,7
Definite
0,20
Note
INCOMMING-0.4kV MCC
Thermal Trip MCCB
High Set O/C Relay or Magnetic Trip MCCB
Protection-Type
CT Rated /
MCCB Capacity
FLA (A)
ISC Max
(kA)
MF x FLA (A)
Pick-Up
Type
TMS
MF x FLA (A)
Pick-Up
Type
TD (s)
0.4kV UNIT-1A SWITCHGEAR
Siemens 7SJ80
630/1
461,9
63
508,13
0,8
IEC - LI
0,1
3233,5
5,13
Definite
0,20
11BFA01GS002
0.4kV UNIT-1B SWITCHGEAR
Siemens 7SJ80
630/1
461,9
63
508,13
0,8
IEC - LI
0,1
3233,5
5,13
Definite
0,20
12BFA01GS001
0.4kV UNIT-2A SWITCHGEAR
Siemens 7SJ80
630/1
461,9
63
508,13
0,8
IEC - LI
0,1
3233,5
5,13
Definite
0,20
12BFA01GS002
0.4kV UNIT-2B SWITCHGEAR
Siemens 7SJ80
630/1
461,9
63
508,13
0,8
IEC - LI
0,1
3233,5
5,13
Definite
0,20
5
10BFA01GS001
0.4kV COMMON-12A SWITCHGEAR
Siemens 7SJ80
630/1
457,3
63
503,07
0,8
IEC - LI
0,1
3201,4
5,08
Definite
0,20
6
10BFA02GS001
0.4kV COMMON-12B SWITCHGEAR
Siemens 7SJ80
630/1
457,3
63
503,07
0,8
IEC - LI
0,1
3201,4
5,08
Definite
0,20
7
10BFA03GS001
0.4kV COAL HANDLING MCC
Siemens 7SJ80
1250/1
1075,5
40
1183,05
0,9
IEC - LI
0,1
7528,5
11,95
Definite
0,20
7
10BFA03GS001
0.4kV COAL HANDLING MCC
Siemens 7SJ80
1250/1
1075,5
40
1183,05
0,9
IEC - LI
0,1
7528,5
11,95
Definite
0,20
No
Tag No.
1
11BFA01GS001
2
3
4
Discription
Note
OUTGOING-0.4kV MCC-1
No
Tag No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
52
53
54
55
56
57
58
59
60
61
62
63
64
65
66
67
68
69
70
71
72
73
74
75
76
77
78
79
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
11PAH20GH001
11PAH10AT010-M01
11LCM21AP110-M01
11LCM22AP110-M01
11MAJ51AP110-M01
11MAJ52AP110-M01
11MAM65AN110-M01
11MAM65AN120-M01
11MAX10AH110
11MAX21AP110-M01
11MAX22AP110-M01
11MAX51AN110-M01
11MAX51AP110-M01
11MAX52AN110-M01
11MAX52AP110-M01
11PUE10AP110-M01
11BUC10
11CHA10
11CJJ10
11CJN10
11MKA10GA050
11PAC21AP101-M01
11PAC22AP101-M01
11PAC21AT001
11QCC11AP001-M01
11QCC12AP001-M01
11QCA11AP001-M01
11QCA12AP001-M01
11QCD11AP001-M01
11QCD12AP001-M01
11HAC70AA152-M01
11HAH01AA152-M01
11HAH40AA102-M01
11HAH40AA152-M01
11HAH41AA102-M01
11HAH41AA104-M01
11HAH41AA152-M01
11HAH42AA102-M01
11HAH42AA104-M01
11HAH42AA152-M01
11HAH81AA152-M01
11HAH81AA102-M01
11HAH82AA152-M01
11HAH82AA102-M01
11HCB01AA101-M01
11HCB10AA101-M01
11HCB10GH001
11HCB10GH002
11HCB10GH003
11HCB10GH004
11HCB10GH005
11HCB10GH006
11HCB10BN101-M01
11HCB10BN102-M01
11HCB10BN103-M01
11HCB10BN104-M01
11HCB10BN106-M01
11HCB10BN105-M01
11HCB20AA101-M01
11HCB20GH001
11HCB20GH002
11HCB20GH003
11HCB20GH004
11HCB20GH005
11HCB20GH006
11HCB20GH007
11HCB20GH008
11HCB20GH009
11HCB20GH010
11HCB20GH011
11HCB20GH012
11HCB20GH013
11HCB20GH014
11HDA12AF301-M01
11HDA11AF301-M01
11HDA51AF201-M01
11HDA52AF201-M01
11HHE10GH001-E11
11HHE10GH010-E11
11HHE11AF101-M01
11HHE21AF101-M01
11HHE31AF101-M01
11HHE41AF101-M01
11HHE20GH001-E11
11HHE30GH001-E11
11HHE40GH001-E11
11HHH10AN601-M01
11HHM01AN401-M01
11HHM01AN601-E11
11HHM02AN401-M01
11HHM02AN601-E11
11HHM03AN401-M01
11HHM03AN601-E11
Discription
Condenser Cleaning System
Actuator Screen
Drains Condensate Pump 1 Motor
Drains Condensate Pump 2 Motor
Vacuum Pump 1 Motor
Vacuum Pump 2 Motor
Waste Steam Condenser Suction Fan 1 Motor
Waste Steam Condenser Suction Fan 2 Motor
Control Oil Tank Heating
Control Oil Pump 1 Motor
Control Oil Pump 2 Motor
Control Oil Cooler Fan 1 Motor
Control Oil Cooler Pump 1 Motor
Control Oil Cooler Fan 2 Motor
Control Oil Cooler Pump 2 Motor
Vacuum Pump Water Box Condenser Motor
Turbine Subdistrib. 220V DC, Socket Outlet, Lighting
Generator Protection, Socket Outlet, Lighting
Central I&C Cabinet, Socket Outlet, Lighting
Automatic Voltage Regulation, Socket Outlet, Lighting
IRIS FLUX TRAC II-R and exciter hood lighting
ACW Booster Pump A
ACW Booster Pump B
Debris Filter to Condenser and ACW
Phosphate Injection Pump Unit 1
Phosphate Injection Pump Unit 1
Hidrazine Injection Pump Unit 1
Hidrazine Injection Pump Unit 1
Ammonia Injection Pump Unit 1
Ammonia Injection Pump Unit 1
MOV Distribution Panel Unit 1
LV Cubicle & Resistor
CMK Motor
Water Cooled Hanger Tubes
Saturated steam
Steam Cooled Convection Cage
Steam Cooled Convection Cage
Convective Superheater I
Convective Superheater I
Convective Superheater I
Convective Superheater II
Convective Superheater II
Convective Superheater II
Intrex Superheater
Intrex Superheater
Intrex Superheater
Intrex Superheater
Sootblowing steam hp
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Bottom ash from Furnace, line 1
Bottom ash from Furnace, line 2
Bottom ash from Furnace
Bottom ash from Furnace
Fuel line 1 (Coal Feeder LCP)
Fuel line 1 (Heat Tracing LCP)
Fuel feeding line 1
Fuel feeding line 2
Fuel feeding line 3
Fuel feeding line 4
Fuel line 2 (Coal Feeder LCP)
Fuel line 3 (Coal Feeder LCP)
Fuel line 4 (Coal Feeder LCP)
Bed material silo
HP air fan 1
HP air fan 1
HP air fan 2
HP air fan 2
HP air fan 3
HP air fan 3
Overload Relay Setting (49)
Type
Starting
Type
Protection-Type
CT Rated /
MCCB Capacity
FLA (A)
F
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
F
F
F
F
F
M
M
F
M
M
M
M
M
M
F
F
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
F
F
F
F
F
F
M
F
F
F
F
F
F
F
F
F
F
F
F
F
F
F
F
F
F
F
F
M
M
M
M
F
F
M
M
M
M
F
F
F
M
M
F
M
F
M
F
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
VFD
VFD
VFD
VFD
FR
FR
FR
FR
DOL
DOL
DOL
DOL
-
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
16
6
6
6
100
100
6
6
25
25
25
6
6
6
6
16
16
16
16
16
6
32
32
16
6
6
6
6
6
6
120
25
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
50
32
32
32
32
6
6
6
6
6
6
6
6
6
6
12,00
1,60
4,41
4,41
81,55
81,55
2,26
2,26
10,83
14,26
14,26
0,99
3,17
0,99
3,17
5,65
10,23
10,23
10,23
10,23
0,15
26,10
26,10
7,56
4,89
4,89
1,06
1,06
1,06
1,06
132,53
23,85
0,74
0,24
0,24
0,50
0,24
0,50
0,24
0,24
0,50
0,50
0,24
0,24
0,48
0,24
0,48
2,87
0,50
1,51
1,51
1,51
1,51
1,51
1,51
0,50
1,51
1,51
1,51
1,51
1,51
1,51
1,78
1,78
1,78
1,78
1,78
1,78
1,78
1,78
1,78
1,78
1,78
1,78
1,78
1,78
3,42
3,42
3,42
3,42
2,96
32,26
21,45
21,45
21,45
21,45
2,96
2,96
2,96
5,65
1,65
1,81
1,65
1,81
1,65
1,81
Thermal Trip MCCB
High Set O/C Relay or Magnetic Trip MCCB
Note
MF x FLA (A)
Class
Thermal Set
Pick-Up (A)
Type
TMS
1,76
4,85
4,85
89,71
89,71
2,48
2,48
11,91
15,68
15,68
1,09
3,49
1,09
3,49
6,21
28,71
28,71
5,38
5,38
1,17
1,17
1,17
1,17
0,82
0,26
0,26
0,55
0,26
0,55
0,26
0,26
0,55
0,55
0,26
0,26
0,53
0,26
0,53
3,15
0,55
0,55
3,76
3,76
3,76
3,76
23,59
23,59
23,59
23,59
6,21
1,82
1,82
1,82
-
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
-
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
16,0
16,0
16,0
16,0
16,0
6,0
16,0
120,0
25,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
50,0
6,0
6,0
6,0
6,0
6,0
6,0
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
Magnetic Set Pick-Up (A)
5
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
5
5
5
5
5
8
8
5
8
8
8
8
8
8
5
5
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
5
5
5
5
5
5
8
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
2
2
2
2
5
5
5
5
5
5
5
5
5
8
8
5
8
5
8
5
80
48
48
48
800
800
48
48
200
200
200
48
48
48
48
128
80
80
80
80
30
256
256
80
48
48
48
48
48
48
600
125
48
48
48
48
48
48
48
48
48
48
48
48
48
48
48
48
48
30
30
30
30
30
30
48
30
30
30
30
30
30
30
30
30
30
30
30
30
30
30
30
30
30
30
30
12
12
12
12
30
250
160
160
160
160
30
30
30
48
48
30
48
30
48
30
Type
TD (s)
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
97
98
99
100
101
102
103
104
105
106
107
108
109
110
111
112
113
114
115
116
117
118
119
120
121
122
11HLA11AA701-M01
11HLA12AA701-M01
11HLB11AN101-E11
11HLB12AN101-E11
11HLB21AN101-E11
11HLB22AN101-E11
11HLE11AA701-M01
11HLE12AA701-M01
11HNA61AA701-M01
11HNA61AA702-M01
11HNA62AA701-M01
11HNA62AA702-M01
11HNC10AN201-E11
11HNC20AN201-E11
11HRB11AF501-M01
11HRB12AF501-M01
11HRC11AN601-M01
11HRC12AN601-M01
11LAB60AA101-M01
11LAB60AA102-M01
11LAB61AA101-M01
11LAB61AA102-M01
11LBA10AA102-M01
-
Primary air to fan 1
Primary air to fan 2
Primary air fan 1
Primary air fan 2
Secondary air fan 1
Secondary air fan 2
Secondary air to fan 1
Secondary air to fan 2
Flue Gas Duct To/From ID Fan 1
Flue Gas Duct To/From ID Fan 1
Flue Gas Duct To/From ID Fan 2
Flue Gas Duct To/From ID Fan 2
ID Fan 1
ID Fan 2
Limestone feeding line 1
Limestone feeding line 2
Limestone feeding fluidization air fan 1
Limestone feeding fluidization air fan 2
Feedwater main valve group area
Feedwater main valve group area
Feedwater main valve group bypass
Feedwater main valve group bypass
Main HP steam
Cooling Fan for GT-1
Air Compressor for IPB
Debris Filter for BFW
M
M
F
F
F
F
M
M
M
M
M
M
F
F
M
M
M
M
M
M
M
M
M
M
M
F
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
VFD
VFD
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
-
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
80
80
16
16
16
16
6
6
6
6
0,09
0,09
1,74
1,74
1,74
1,74
0,12
0,12
0,69
0,69
0,69
0,69
1,74
1,74
1,31
1,31
53,51
53,51
11,36
11,36
11,36
11,36
0,71
2,15
1,08
14,88
0,10
0,10
0,13
0,13
0,76
0,76
0,76
0,76
1,44
1,44
58,86
58,86
12,49
12,49
12,49
12,49
0,78
2,37
1,18
-
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
-
1,00
1,00
1,00
1,00
1,00
1,00
1,00
6,0
6,0
6,0
6,0
6,0
6,0
6,0
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
8
8
5
5
5
5
8
8
8
8
8
8
5
5
2
2
8
8
8
8
8
8
8
8
8
5
48
48
30
30
30
30
48
48
48
48
48
48
30
30
12
12
640
640
128
128
128
128
48
48
48
30
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
OUTGOING-0.4kV MCC-2
No
Tag No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
52
53
54
55
56
57
58
59
60
61
62
63
64
65
66
67
68
69
70
71
72
73
74
75
76
77
78
79
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
12PAH20GH001
12PAH10AT010-M01
12LCM21AP110-M01
12LCM22AP110-M01
12MAJ51AP110-M01
12MAJ52AP110-M01
12MAM65AN110-M01
12MAM65AN120-M01
12MAX10AH110
12MAX21AP110-M01
12MAX22AP110-M01
12MAX51AN110-M01
12MAX51AP110-M01
12MAX52AN110-M01
12MAX52AP110-M01
12PUE10AP110-M01
12BUC10
12CHA10
12CJJ10
12CJN10
12MKA10GA050
12PAC21AP101-M01
12PAC22AP101-M01
12PAC21AT001
12QCC11AP001-M01
12QCC12AP001-M01
12QCA11AP001-M01
12QCA12AP001-M01
12QCD11AP001-M01
12QCD12AP001-M01
12HAC70AA152-M01
12HAH01AA152-M01
12HAH40AA102-M01
12HAH40AA152-M01
12HAH41AA102-M01
12HAH41AA104-M01
12HAH41AA152-M01
12HAH42AA102-M01
12HAH42AA104-M01
12HAH42AA152-M01
12HAH81AA152-M01
12HAH81AA102-M01
12HAH82AA152-M01
12HAH82AA102-M01
12HCB01AA101-M01
12HCB10AA101-M01
12HCB10GH001
12HCB10GH002
12HCB10GH003
12HCB10GH004
12HCB10GH005
12HCB10GH006
12HCB10BN101-M01
12HCB10BN102-M01
12HCB10BN103-M01
12HCB10BN104-M01
12HCB10BN106-M01
12HCB10BN105-M01
12HCB20AA101-M01
12HCB20GH001
12HCB20GH002
12HCB20GH003
12HCB20GH004
12HCB20GH005
12HCB20GH006
12HCB20GH007
12HCB20GH008
12HCB20GH009
12HCB20GH010
12HCB20GH012
12HCB20GH012
12HCB20GH013
12HCB20GH014
12HDA12AF301-M01
12HDA11AF301-M01
12HDA51AF201-M01
11HDA52AF201-M01
12HHE10GH001-E11
12HHE10GH010-E11
12HHE11AF101-M01
12HHE21AF101-M01
12HHE31AF101-M01
12HHE41AF101-M01
12HHE20GH001-E11
12HHE30GH001-E11
12HHE40GH001-E11
12HHH10AN601-M01
12HHM01AN401-M01
12HHM01AN601-E11
12HHM02AN401-M01
12HHM02AN601-E11
12HHM03AN401-M01
12HHM03AN601-E11
12HLA11AA701-M01
Discription
Condenser Cleaning System
Actuator Screen
Drains Condensate Pump 1 Motor
Drains Condensate Pump 2 Motor
Vacuum Pump 1 Motor
Vacuum Pump 2 Motor
Waste Steam Condenser Suction Fan 1 Motor
Waste Steam Condenser Suction Fan 2 Motor
Control Oil Tank Heating
Control Oil Pump 1 Motor
Control Oil Pump 2 Motor
Control Oil Cooler Fan 1 Motor
Control Oil Cooler Pump 1 Motor
Control Oil Cooler Fan 2 Motor
Control Oil Cooler Pump 2 Motor
Vacuum Pump Water Box Condenser Motor
Turbine Subdistrib. 220V DC, Socket Outlet, Lighting
Generator Protection, Socket Outlet, Lighting
Central I&C Cabinet, Socket Outlet, Lighting
Automatic Voltage Regulation, Socket Outlet, Lighting
IRIS FLUX TRAC II-R and exciter hood lighting
ACW Booster Pump A
ACW Booster Pump B
Debris Filter to Condenser and ACW
Phosphate Injection Pump Unit 1
Phosphate Injection Pump Unit 1
Hidrazine Injection Pump Unit 1
Hidrazine Injection Pump Unit 1
Ammonia Injection Pump Unit 1
Ammonia Injection Pump Unit 1
MOV Distribution Panel Unit 1
LV Cubicle & Resistor
CMK Motor
Water Cooled Hanger Tubes
Saturated steam
Steam Cooled Convection Cage
Steam Cooled Convection Cage
Convective Superheater I
Convective Superheater I
Convective Superheater I
Convective Superheater II
Convective Superheater II
Convective Superheater II
Intrex Superheater
Intrex Superheater
Intrex Superheater
Intrex Superheater
Sootblowing steam hp
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Sootblowing steam, 1 back pass
Bottom ash from Furnace, line 1
Bottom ash from Furnace, line 2
Bottom ash from Furnace
Bottom ash from Furnace
Fuel line 1 (Coal Feeder LCP)
Fuel line 1 (Heat Tracing LCP)
Fuel feeding line 1
Fuel feeding line 2
Fuel feeding line 3
Fuel feeding line 4
Fuel line 2 (Coal Feeder LCP)
Fuel line 3 (Coal Feeder LCP)
Fuel line 4 (Coal Feeder LCP)
Bed material silo
HP air fan 1
HP air fan 1
HP air fan 2
HP air fan 2
HP air fan 3
HP air fan 3
Primary air to fan 1
Type
Starting
Type
Protection-Type
CT Rated /
MCCB Capacity
FLA (A)
F
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
F
F
F
F
F
M
M
F
M
M
M
M
M
M
F
F
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
F
F
F
F
F
F
M
F
F
F
F
F
F
F
F
F
F
F
F
F
F
F
F
F
F
F
F
M
M
M
M
F
F
M
M
M
M
F
F
F
M
M
F
M
F
M
F
M
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
VFD
VFD
VFD
VFD
FR
FR
FR
FR
DOL
DOL
DOL
DOL
DOL
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
16
6
6
6
100
100
6
6
25
25
25
6
6
6
6
16
16
16
16
16
6
32
32
16
6
6
6
6
6
6
120
25
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
50
32
32
32
32
6
6
6
6
6
6
6
6
6
6
6
12,00
1,60
4,41
4,41
81,55
81,55
2,26
2,26
10,83
14,26
14,26
0,99
3,17
0,99
3,17
5,65
10,23
10,23
10,23
10,23
0,15
26,10
26,10
7,56
4,89
4,89
1,06
1,06
1,06
1,06
132,53
23,85
0,74
0,24
0,24
0,50
0,24
0,50
0,24
0,24
0,50
0,50
0,24
0,24
0,48
0,24
0,48
2,87
0,50
1,51
1,51
1,51
1,51
1,51
1,51
0,50
1,51
1,51
1,51
1,51
1,51
1,51
1,78
1,78
1,78
1,78
1,78
1,78
1,78
1,78
1,78
1,78
1,78
1,78
1,78
1,78
3,42
3,42
3,42
3,42
2,96
32,26
21,45
21,45
21,45
21,45
2,96
2,96
2,96
5,65
1,65
1,81
1,65
1,81
1,65
1,81
0,09
Overload Relay Setting (49)
MF x FLA (A)
Class
1,76
4,85
4,85
89,71
89,71
2,48
2,48
11,91
15,68
15,68
1,09
3,49
1,09
3,49
6,21
28,71
28,71
5,38
5,38
1,17
1,17
1,17
1,17
0,82
0,26
0,26
0,55
0,26
0,55
0,26
0,26
0,55
0,55
0,26
0,26
0,53
0,26
0,53
3,15
0,55
0,55
3,76
3,76
3,76
3,76
23,59
23,59
23,59
23,59
6,21
1,82
1,82
1,82
0,10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
Thermal Set
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
-
Thermal Trip MCCB
Pick-Up (A)
Type
16,0
16,0
16,0
16,0
16,0
6,0
16,0
120,0
25,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
6,0
50,0
6,0
6,0
6,0
6,0
6,0
6,0
-
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
-
TMS
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
-
High Set O/C Relay or Magnetic Trip MCCB
Magnetic Set Pick-Up (A)
Type
TD (s)
5
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
5
5
5
5
5
8
8
5
8
8
8
8
8
8
5
5
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
5
5
5
5
5
5
8
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
2
2
2
2
5
5
5
5
5
5
5
5
5
8
8
5
8
5
8
5
8
80
48
48
48
800
800
48
48
200
200
200
48
48
48
48
128
80
80
80
80
30
256
256
80
48
48
48
48
48
48
600
125
48
48
48
48
48
48
48
48
48
48
48
48
48
48
48
48
48
30
30
30
30
30
30
48
30
30
30
30
30
30
30
30
30
30
30
30
30
30
30
30
30
30
30
30
12
12
12
12
30
250
160
160
160
160
30
30
30
48
48
30
48
30
48
30
48
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Note
98
99
100
101
102
103
104
105
106
107
108
109
110
111
112
113
114
115
116
117
118
119
120
121
122
12HLA12AA701-M01
12HLB11AN101-E11
12HLB12AN101-E11
12HLB21AN101-E11
12HLB22AN101-E11
12HLE11AA701-M01
12HLE12AA701-M01
12HNA61AA701-M01
12HNA61AA702-M01
12HNA62AA701-M01
12HNA62AA702-M01
12HNC10AN201-E11
12HNC20AN201-E11
12HRB11AF501-M01
12HRB12AF501-M01
12HRC11AN601-M01
12HRC12AN601-M01
12LAB60AA101-M01
12LAB60AA102-M01
12LAB61AA101-M01
12LAB61AA102-M01
12LBA10AA102-M01
-
Primary air to fan 2
Primary air fan 1
Primary air fan 2
Secondary air fan 1
Secondary air fan 2
Secondary air to fan 1
Secondary air to fan 2
Flue Gas Duct To/From ID Fan 1
Flue Gas Duct To/From ID Fan 1
Flue Gas Duct To/From ID Fan 2
Flue Gas Duct To/From ID Fan 2
ID Fan 1
ID Fan 2
Limestone feeding line 1
Limestone feeding line 2
Limestone feeding fluidization air fan 1
Limestone feeding fluidization air fan 2
Feedwater main valve group area
Feedwater main valve group area
Feedwater main valve group bypass
Feedwater main valve group bypass
Main HP steam
Cooling Fan for GT-1
Air Compressor for IPB
Debris Filter for BFW
M
F
F
F
F
M
M
M
M
M
M
F
F
M
M
M
M
M
M
M
M
M
M
M
F
DOL
DOL
DOL
DOL
DOL
DOL
DOL
VFD
VFD
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
-
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
80
80
16
16
16
16
6
6
6
6
0,09
1,74
1,74
1,74
1,74
0,12
0,12
0,69
0,69
0,69
0,69
1,74
1,74
1,31
1,31
53,51
53,51
11,36
11,36
11,36
11,36
0,71
2,15
1,08
14,88
0,10
0,13
0,13
0,76
0,76
0,76
0,76
1,44
1,44
58,86
58,86
12,49
12,49
12,49
12,49
0,78
2,37
1,18
-
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
-
1,00
1,00
1,00
1,00
1,00
1,00
1,00
6,0
6,0
6,0
6,0
6,0
6,0
6,0
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
8
5
5
5
5
8
8
8
8
8
8
5
5
2
2
8
8
8
8
8
8
8
8
8
5
48
30
30
30
30
48
48
48
48
48
48
30
30
12
12
640
640
128
128
128
128
48
48
48
30
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
No
Tag No.
Discription
Type
Starting
Type
Protection-Type
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
39
40
41
42
43
44
45
46
47
48
49
50
51
52
53
54
55
56
57
58
59
60
61
68
69
70
71
72
73
74
75
76
77
78
79
10EMK20AF001
10EMK20AT001
10ETD10GH601
10HRA11AP701-M01
10HRA11AP701
10HRA12AP701-M01
10HRA12AP701
10HRA13AP701-M01
10HRA13AP701
10QEA91AT001
10QEA92AT001
10QCC10AM001-M01
10QCA10GH201
10QCA10AM001-M01
10QCD10AM001-M01
10EGC11AP501-M01
10EGC12AP501-M01
10EGC11AP502-M01
10EGC12AP502-M01
10EGC10AP501
LMS-OHC-01
STG-OHC-01
SF-MH-01
SF-MH-02
JB-ASH-EF-01
Hold
Hold
Hold
11LBG20AA101
10GHC21AA101
10GHC22AA101
10GUC40AP401
10GUC40AP402
10GUC30AP401
10GUC30AP402
10GMC11AP401
10GMC11AP402
10GMC13AP401
10GMC13AP402
10GMC15AP401
10GMC15AP402
10GMC17AP401
10GMC17AP402
10GMC19AP401
10GMC19AP402
10GMC22AP401
10GMC22AP402
10GMC24AP401
10GMC24AP402
10GMC26AP401
10GMC26AP402
Hold
Hold
Hold
Hold
1100NLP001
1130NLP001
1040NLP001
1150NLP001
1070NLP001
119NLP001
1170NLP001
1090NLP001
1000LP001
1000LP002
1010NLP001
1240NLP001
Big Bag Pneumatic Panel
Limestone Silo Vent Filter
PLC PANEL & HMI SYSTEM FOR LIMESTONE FEED SYSTEM
Ammonia Supply Pump-1
Ammonia Pump-1 Stroke Adjustment
Ammonia Supply Pump-2
Ammonia Pump-2Stroke Adjustment
Ammonia Supply Pump-3
Ammonia Pump-3Stroke Adjustment
Air dryer #1
Air dryer #2
Agitator Phosphate Tank
LCP Injection Package
Agitator for Oxygen Scavenger Tank
Agitator for Ammonia Tank
Fuel Oil Supply Pump A
Fuel Oil Supply Pump B
Fuel Oil Unloading Pump A
Fuel Oil Unloading Pump B
Fuel Oil Dispenser
OVERHEAD CRANE LIMESTONE BUILDING
OVERHEAD CRANE FOR STG
Hoist for Sand Feeding / Bed Material Filling 1
Hoist for Sand Feeding / Bed Material Filling 2
JB for Exhaust Fan Ash Compressor Building
OVERHEAD CRANE FOR CWP
OVERHEAD CRANE FOR CWP PIT
OVERHEAD CRANE FOR WORKSHOP
Aux Steam Header (Unit #1) To (Unit #2)
Demin Water Distribution to CCW Expansion Tank
Demin Water Distribution to CCW Expansion Tank
Ash Run Of Pump A
Ash Run Of Pump B
Coal Run Off Pump A
Coal Run Off Pump B
Chem. Cleaning Pump A
Chem. Cleaning Pump B
Chem. Waste Water Pump 1 A
Chem. Waste Water Pump 1 B
Chem. Waste Water Pump 2 A
Chem. Waste Water Pump 2 B
Chem. Waste Water Pump 3 A
Chem. Waste Water Pump 3 B
Chem. Waste Water Pump 4 A
Chem. Waste Water Pump 4 B
Chem. Waste Water Pump 5 A
Chem. Waste Water Pump 5 B
Chem. Waste Water Pump 6 A
Chem. Waste Water Pump 6 B
Oily Waste Pump 1 A
Oily Waste Pump 1 B
Oily Waste Pump 2 A
Oily Waste Pump 2 B
Oily Waste Pump 3 A
Oily Waste Pump 3 B
LIMESTONE
BOILER
AIR COMP
RWT & DEMIN PUMP HOUSE
MOSQUE
ADMIN BUILDING
HSD TANK
CANTEEN
STREET LIGHTING
STREET LIGHTING
TURBINE HOUSE
POWER BLOCK
F
F
F
M
F
M
F
M
F
F
F
M
F
M
M
M
M
M
M
F
F
F
F
F
F
F
F
F
F
F
F
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
M
F
F
F
F
F
F
F
F
F
F
F
F
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
-
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
OUTGOING-0.4kV MCC-12
CT Rated / MCCB
Overload Relay Setting (49)
FLA (A)
Capacity
MF x FLA (A)
Class
Thermal Set
6
6
6
6
6
6
6
6
6
16
16
6
16
10
10
50
50
10
10
10
50
125
32
32
50
50
40
16
6
6
6
16
16
6
6
16
16
6
6
6
6
6
6
6
6
16
16
6
6
6
6
6
6
6
6
10
40
16
25
63
100
25
100
25
25
50
100
1,80
7,25
1,44
1,83
0,22
1,83
0,22
1,83
0,04
16,95
16,95
4,85
17,39
4,85
4,85
36,44
36,44
7,32
7,32
31,06
36,08
134,03
24,06
24,06
15,46
28,87
18,76
10,10
0,68
0,78
0,78
4,62
4,62
1,15
1,15
2,60
2,60
0,09
0,09
0,09
0,09
0,09
0,09
0,09
0,09
2,09
2,09
1,59
1,59
1,59
1,59
1,59
1,59
1,59
1,59
8,66
36,08
4,33
21,65
43,30
72,17
18,76
50,52
10,10
8,66
28,87
72,17
2,01
2,01
2,01
5,33
5,33
5,33
40,08
40,08
8,06
8,06
5,08
5,08
1,27
1,27
2,86
2,86
0,30
0,30
0,30
0,30
0,30
0,30
0,30
0,30
2,30
2,30
1,75
1,75
1,75
1,75
1,75
1,75
1,75
1,75
-
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
10
-
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
1,00
Thermal Trip MCCB
Pick-Up (A)
Type
6,0
6,0
6,0
6,0
6,0
6,0
16,0
16,0
16,0
10,0
50,0
125,0
32,0
32,0
50,0
50,0
40,0
16,0
6,0
6,0
6,0
10,0
40,0
16,0
25,0
63,0
100,0
25,0
100,0
25,0
25,0
50,0
100,0
TMS
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
High Set O/C Relay or Magnetic Trip MCCB
Magnetic Set Pick-Up (A)
Type
TD (s)
5
5
5
8
5
8
5
8
5
5
5
8
5
8
8
8
8
8
8
5
5
5
5
5
5
5
5
5
5
5
5
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
5
5
5
5
5
5
5
5
5
5
5
5
30
30
30
48
30
48
30
48
30
80
80
48
80
80
80
400
400
80
80
50
250
625
160
160
250
250
200
80
30
30
30
128
128
48
48
128
128
48
48
48
48
48
48
48
48
128
128
48
48
48
48
48
48
48
48
50
200
80
125
315
500
125
500
125
125
250
500
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
Note
INCOMMING-0.4kV EDG MCC
No
Thermal Trip MCCB
High Set O/C Relay or Magnetic Trip MCCB
MF x FLA
Pick-Up
Type
Trip Time
(A)
Protection-Type
CT Rated /
MCCB Capacity
FLA (A)
ISC Max
(kA)
MF x FLA (A)
Pick-Up
Type
TMS
0.4kV UNIT-1A SWITCHGEAR
7SJ80
630/1
388,6
63
427,43
0,7
IEC - LI
0,5
2720,0
4,3
Definite
0,20
0.4kV EDG BUS
7SJ80
630/1
388,6
63
427,43
0,7
IEC - LI
0,5
2720,0
4,3
Definite
0,20
0.4kV UNIT-2A SWITCHGEAR
7SJ80
630/1
388,6
63
427,43
0,7
IEC - LI
0,5
2720,0
4,3
Definite
0,20
0.4kV EDG BUS
7SJ80
630/1
388,6
63
427,43
0,7
IEC - LI
0,5
2720,0
4,3
Definite
0,20
0.4kV COMMON-12A SWITCHGEAR
7SJ80
630/1
408,6
63
449,41
1,0
IEC - LI
0,7
2859,9
4,5
Definite
0,20
0.4kV EDG BUS
7SJ80
630/1
408,6
63
449,41
1,0
IEC - LI
0,7
2859,9
4,5
Definite
0,20
Tag No.
Discription
0.4kV ESS UNIT-1 MCC
1
11BMA01GS001
2
0.4kV ESS UNIT-2 MCC
3
12BMA01GS001
4
0.4kV ESS COMMON-12 MCC
5
6
10BMA01GS001
Note
No
Tag No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
11MAA16AH110
11MAV10AH110
11MAV15AN110-M01
11MAV15AN120-M01
11MAV21AP110-M01
11MAV22AP110-M01
11MAV71AP110-M01
11MAV72AP110-M01
11MKA10AH110
11CJJ11
11CRU13
11PGC11AP101-M01
11PGC12AP101-M01
JC101A
11HNE10GH601
11QUU10
11HAD03AA101-M01
11LBH10AA101-M01
11LBH10AA201-M01
11LCQ10AA101-M01
11BRA01GS001
11BUA01GS001
11BUA01GS001
Discription
Type
Casing Heating
M
Lube Oil Tank Heating
M
Oil Mist Separator Fan 1 Motor
M
Oil Mist Separator Fan 2 Motor
M
Lube Oil Pump 1 Motor
M
Lube Oil Pump 2 Motor
M
Jacking Oil Pump 1 Motor
M
Jacking Oil Pump 2 Motor
M
Generator Anti-Condensation Heater
M
Server Cabinet, Socket Outlet, Lighting, Heating, Fan (if applicable) F
Printer
F
Closed Cooling Water Pump A
M
Closed Cooling Water Pump B
M
Boiler Elevator Unit-1
F
Unit 1 CEMS Panel Termina E2
F
Sampling Rack 1 (Thermal Control Unit)
F
Steam Drum Overflow
M
Start-up steam system
M
Start-up steam system
M
Continous Blow-down tank
M
Transformer & Differential Protection Panel-1
F
Tariff Metering Panel-1
F
PDP UPS-1
F
PDP BC-1 A
F
PDP BC-1 B
F
Starting Type
Protection-Type
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
-
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
OUTGOING-0.4kV ESSETIAL MCC-1
CT Rated/ MCCB
Overload Relay Setting (49)
FLA (A)
Capacity
MF x FLA (A)
Class
25
10,25
11,27
10
16
7,22
7,94
10
6
3,26
3,59
10
6
3,26
3,59
10
50
32,11
35,32
10
50
32,11
35,32
10
100
66,13
72,75
10
100
66,13
72,75
10
16
5,77
6,35
10
16
23,09
6
8,66
200
100,48
110,53
10
200
100,48
110,53
10
100
144,34
25
36,08
25
36,08
6
0,48
0,53
10
16
7,45
8,19
10
16
3,72
4,10
10
6
0,50
0,55
10
10
14,43
6
8,66
250
360,84
25
36,08
25
36,08
-
Thermal Trip MCCB
Thermal Set Pick-Up (A)
Type
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
1,00
16
FIXED
1,00
6
FIXED
FIXED
FIXED
1,00
100
FIXED
1,00
25
FIXED
1,00
25
FIXED
FIXED
FIXED
FIXED
FIXED
1,00
10
FIXED
1,00
6
FIXED
1,00
250
FIXED
1,00
25
FIXED
1,00
25
FIXED
TMS
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
High Set O/C Relay or Magnetic Trip MCCB
Magnetic Set Pick-Up (A)
Type
Trip Time
8
200
FIXED
FIXED
8
128
FIXED
FIXED
8
48
FIXED
FIXED
8
48
FIXED
FIXED
8
400
FIXED
FIXED
8
400
FIXED
FIXED
8
800
FIXED
FIXED
8
800
FIXED
FIXED
8
128
FIXED
FIXED
5
80
FIXED
FIXED
5
30
FIXED
FIXED
8
1600
FIXED
FIXED
8
1600
FIXED
FIXED
5
500
FIXED
FIXED
5
125
FIXED
FIXED
5
125
FIXED
FIXED
8
48
FIXED
FIXED
8
128
FIXED
FIXED
8
128
FIXED
FIXED
8
48
FIXED
FIXED
5
50
FIXED
FIXED
5
30
FIXED
FIXED
5
1250
FIXED
FIXED
5
125
FIXED
FIXED
5
125
FIXED
FIXED
Note
No
Tag No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
12MAA16AH110
12MAV10AH110
12MAV15AN110-M01
12MAV15AN120-M01
12MAV21AP110-M01
12MAV22AP110-M01
12MAV71AP110-M01
12MAV72AP110-M01
12MKA10AH110
12CJJ11
12CRU13
12PGC11AP101-M01
12PGC12AP101-M01
JC102A
12HNE10GH601
12QUU10
12HAD03AA101-M01
12LBH10AA101-M01
12LBH10AA201-M01
12LCQ10AA101-M01
12BRA01GS001
12BUA01GS001
12BUA01GS001
Discription
Type
Casing Heating
M
Lube Oil Tank Heating
M
Oil Mist Separator Fan 1 Motor
M
Oil Mist Separator Fan 2 Motor
M
Lube Oil Pump 1 Motor
M
Lube Oil Pump 2 Motor
M
Jacking Oil Pump 1 Motor
M
Jacking Oil Pump 2 Motor
M
Generator Anti-Condensation Heater
M
Server Cabinet, Socket Outlet, Lighting, Heating, Fan (if applicable) F
Printer
F
Closed Cooling Water Pump A
M
Closed Cooling Water Pump B
M
Boiler Elevator Unit-1
F
Unit 1 CEMS Panel Termina E2
F
Sampling Rack 1 (Thermal Control Unit)
F
Steam Drum Overflow
M
Start-up steam system
M
Start-up steam system
M
Continous Blow-down tank
M
Transformer & Differential Protection Panel-1
F
Tariff Metering Panel-1
F
PDP UPS-1
F
PDP BC-1 A
F
PDP BC-1 B
F
Starting Type Protection-Type
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
DOL
-
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
MCCB
OUTGOING-0.4kV ESSETIAL MCC-2
CT Rated /
Overload Relay Setting (49)
Thermal Trip MCCB
FLA (A)
MCCB Capacity
MF x FLA (A)
Class
Thermal Set Pick-Up (A)
Type
25
10,25
11,27
10
FIXED
16
7,22
7,94
10
FIXED
6
3,26
3,59
10
FIXED
6
3,26
3,59
10
FIXED
50
32,11
35,32
10
FIXED
50
32,11
35,32
10
FIXED
100
66,13
72,75
10
FIXED
100
66,13
72,75
10
FIXED
16
5,77
6,35
10
FIXED
16
23,09
1,00
16
FIXED
6
8,66
1,00
6
FIXED
200
100,48
110,53
10
FIXED
200
100,48
110,53
10
FIXED
100
144,34
1,00
100
FIXED
25
36,08
1,00
25
FIXED
25
36,08
1,00
25
FIXED
6
0,48
0,53
10
FIXED
16
7,45
8,19
10
FIXED
16
3,72
4,10
10
FIXED
6
0,50
0,55
10
FIXED
10
14,43
1,00
10
FIXED
6
8,66
1,00
6
FIXED
250
360,84
1,00
250
FIXED
25
36,08
1,00
25
FIXED
25
36,08
1,00
25
FIXED
TMS
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
FIXED
High Set O/C Relay or Magnetic Trip MCCB
Magnetic Set Pick-Up (A)
Type
Trip Time
8
200
FIXED
FIXED
8
128
FIXED
FIXED
8
48
FIXED
FIXED
8
48
FIXED
FIXED
8
400
FIXED
FIXED
8
400
FIXED
FIXED
8
800
FIXED
FIXED
8
800
FIXED
FIXED
8
128
FIXED
FIXED
5
80
FIXED
FIXED
5
30
FIXED
FIXED
8
1600
FIXED
FIXED
8
1600
FIXED
FIXED
5
500
FIXED
FIXED
5
125
FIXED
FIXED
5
125
FIXED
FIXED
8
48
FIXED
FIXED
8
128
FIXED
FIXED
8
128
FIXED
FIXED
8
48
FIXED
FIXED
5
50
FIXED
FIXED
5
30
FIXED
FIXED
5
1250
FIXED
FIXED
5
125
FIXED
FIXED
5
125
FIXED
FIXED
Note
No
Tag No.
1
2
3
4
5
STG-HPDB-201
11BRA01GS001
12BRA01GS001
Discription
HVAC Control Room (at HVAC room STG Building)
Emergency Lighting Panel
Jockey Pump
PDP UPS-1
PDP UPS-2
Type
Starting Type
Protection-Type
F
F
M
F
F
DOL
-
MCCB
MCCB
MCCB
MCCB
MCCB
OUTGOING-0.4kV ESSETIAL MCC-12
CT Rated / MCCB
Overload Relay Setting (49)
FLA (A)
Capacity
MF x FLA (A)
Class
320
378,89
200
154,44
25
19,34
21,28
10
250
144,19
250
144,20
-
Thermal Set
100%
100%
100%
100%
Thermal Trip MCCB
Pick-Up (A)
Type
320
FIXED
200
FIXED
FIXED
250
FIXED
250
FIXED
TMS
FIXED
FIXED
FIXED
FIXED
FIXED
High Set O/C Relay or Magnetic Trip MCCB
Magnetic Set Pick-Up (A)
Type
Trip Time
5
1600
FIXED
FIXED
5
1000
FIXED
FIXED
8
200
FIXED
FIXED
5
1250
FIXED
FIXED
5
1250
FIXED
FIXED
Note
PROTECTIVE RELAY SETTING & COORDINATION
STUDY
Timor-1 CFSPP Project
Issued
2020-06-26
Project Document No: T1-PP-000-ELE-STU-00003
ATTACHMENT 3
COORDINATION C U R V E
REV.
0
Amps X 100 LV-1 ESS MCC (Nom. kV=0.4, Plot Ref. kV=0.4)
.5
1
3
5
10
30
50
100
300
1K
500
CEssMcc1-12
Ampacity
300
234.9 Amps
3K
5K
10K
1K
500
Siemens
7SJ80
CT Ratio 630:1
IEC - Long Inverse
Pickup = 0.7 (0.1 - 4 Sec - 1A)
Time Dial = 0.5
3x = 30 s, 5x = 15 s, 8x = 8.57 s
Inst = 4.3 (0.1 - 35 Sec - 1A)
Time Delay = 0.2 s
CBEssMcc1-12
50
1K
Relay3 - P
OC1
Siemens
3VF5 (Adj.)
Size = 200 Amps
Thermal Trip = 100%
Magnetic Trip = 6
100
500
300
CB1LV8
100
±
50
R
OL 3 - OL
Siemens
3UF7
Class 10 (3-pole)
Pickup = 110.5 (20 - 200 Primary)
30
10
Relay3
10
5
5
CEssMcc1-12 - P
1 - 3/C 120 mm²
Copper XLPE
Tc = 90C
Plotted - 1 x 120 mm²
3
3
1
Seconds
Seconds
LV-1 ESS MCC
30
CBEssMcc1-12
1
OL 3
Closed Cooling Water Pump-100%
55 KW
.5
.5
.3
.1
.1
.05
.05
.03
.03
.01
.5
1
3
5
10
30
50
100
300
500
1K
Amps X 100 LV-1 ESS MCC (Nom. kV=0.4, Plot Ref. kV=0.4)
Project:
Location:
Contract:
Engineer:
Filename:
Timor-1 CFSPP Project
Kupang, NTT, Indonesia
0389.PJ/DAN.02.01/010000/2019
YHN
D:\File Penting Nafis\Kerja Bismillah !!\PLN - gawe\Koordinasi Proteksi Relay PL
Date: 09-04-2022
SN:
Rev: Base
Fault: Phase
3K
5K
.01
10K
ETAP Star 19.0.1C
Closed Cooling Water Pump
55 kW
.3
Amps X 100 Bus1LV1 (Nom. kV=0.4, Plot Ref. kV=0.4)
.5
1
3
5
10
30
50
100
300
1K
3K
5K
10K
1K
CEssMcc1-14
Ampacity
500
500
300
98.6 Amps
300
100
CBEss1MCC14
100
30
10
30
5
.5
.1
1
.5
.1
.05
.03
.03
.5
1
3
5
10
30
50
100
300
1K
3K
5K
.01
10K
Amps X 100 Bus1LV1 (Nom. kV=0.4, Plot Ref. kV=0.4)
ETAP Star 19.0.1C
Project:
Location:
Contract:
Engineer:
Filename:
Timor-1 CFSPP Project
Kupang, NTT, Indonesia
0389.PJ/DAN.02.01/010000/2019
YHN
D:\File Penting Nafis\Kerja Bismillah !!\PLN - gawe\
Date: 08-28-2022
SN:
Rev: Base
Fault: Phase
71.43 kVA
CEssMcc1-14 - P
.01
CEssMcc1-14
1-4/C 35
.3
∆ 0.194 s
.05
CBEss1MCC14
Boiler Elevator Unit-1
.3
3
Seconds
1
LV-1 ESS MCC
10
Siemens
7SJ80
CT Ratio 630:1
IEC - Long Inverse
Pickup = 0.7 (0.1 - 4 Sec - 1A)
Time Dial = 0.5
3x = 30 s, 5x = 15 s, 8x = 8.57 s
Inst = 4.3 (0.1 - 35 Sec - 1A)
Time Delay = 0.2 s
3
R
50
Relay3 - P
OC1
5
CB1LV8
±
Siemens
3VF3 (Fixed)
Size = 100 Amps
Thermal Trip = Fixed
Magnetic Trip = Fixed
50
Seconds
1K
Relay3
Amps X 100 Bus0LV1 (Nom. kV=0.4, Plot Ref. kV=0.4)
.5
1
3
5
10
30
50
100
300
500
1K
3K
5K
10K
1K
1K
500
500
CEssMcc0-1
Ampacity
300
300
Relay6 - P
OC1
653.1 Amps
HVAC Control Room
FLA
Siemens
7SJ80
CT Ratio 630:1
IEC - Long Inverse
Pickup = 1 (0.1 - 4 Sec - 1A)
Time Dial = 0.7
3x = 42 s, 5x = 21 s, 8x = 12 s
Inst = 4.5 (0.1 - 35 Sec - 1A)
Time Delay = 0.2 s
378.9 Amps
100
50
30
100
50
30
CB0LV7
CBEssMcc0-1
10
R
5
10
5
3
3
CEssMcc0-1 - P
2 - 4/C 240 mm²
Copper XLPE
Tc = 90C
Plotted - 1 x 240 mm²
1
.3
.3
.1
.1
.05
.03
.03
.01
5
10
30
50
100
300
500
1K
Amps X 100 Bus0LV1 (Nom. kV=0.4, Plot Ref. kV=0.4)
Project:
Location:
Contract:
Engineer:
Filename:
Timor-1 CFSPP Project
Kupang, NTT, Indonesia
0389.PJ/DAN.02.01/010000/2019
YHN
D:\File Penting Nafis\Kerja Bismillah !!\PLN - gawe\Koordinasi Proteksi Relay PLT
Date: 09-04-2022
SN:
Rev: Base
Fault: Phase
3K
5K
.01
10K
ETAP Star 19.0.1C
CEssMcc0-1
262.5 kVA
.05
3
CBEssMcc0-1
2-4/C 240
HVAC Control Room
.5
1
LV-12 ESS COMMON MCC
1
.5
.5
Relay6
Seconds
Seconds
±
Siemens
3VF5 (Adj.)
Size = 315 Amps
Thermal Trip = 100%
Magnetic Trip = 1
Amps X 100 Bus1LV2 (Nom. kV=0.4, Plot Ref. kV=0.4)
.5
1
3
5
1K
10
30
50
100
300
500
1K
3K
5K
10K
1K
CableMCC1-4
Ampacity
500
500
110.8 Amps
Relay4 - P
OC1
300
300
Siemens
7SJ80
CT Ratio 630:1
IEC - Long Inverse
Pickup = 0.8 (0.1 - 4 Sec - 1A)
Time Dial = 0.1
3x = 6 s, 5x = 3 s, 8x = 1.71 s
Inst = 5.1 (0.1 - 35 Sec - 1A)
Time Delay = 0.2 s
Vacuum Pump 1 Motor-100%
45 KW
100
50
30
CB1LV9
100
±
LV-1AB MCC
Siemens
3UF7
Class 10 (3-pole)
Pickup = 89.71 (10 - 100 Primary)
10
CBMCC1-4
Siemens
3VF3 (Adj.)
Size = 100 Amps
Thermal Trip = 100%
Magnetic Trip = 6
3
5
3
Seconds
OL3
CableMCC1-4 - P
1 - 3/C 35 mm²
Copper XLPE
Tc = 90C
Plotted - 1 x 35 mm²
1
.5
.3
.3
.1
.1
.05
.05
.03
.03
.01
.5
1
3
5
10
30
50
100
300
500
1K
Amps X 100 Bus1LV2 (Nom. kV=0.4, Plot Ref. kV=0.4)
Project:
Location:
Contract:
Engineer:
Filename:
Timor-1 CFSPP Project
Kupang, NTT, Indonesia
0389.PJ/DAN.02.01/010000/2019
YHN
D:\File Penting Nafis\Kerja Bismillah !!\PLN - gawe\Koordinasi Proteksi Relay PLT
Date: 09-05-2022
SN:
Rev: Base
Fault: Phase
3K
5K
.01
10K
ETAP Star 19.0.1C
45 kW
.5
1
Vacuum Pump 1 Motor
Seconds
CBMCC1-4
5
Relay4
30
OL3 - OL
10
R
50
Amps X 10 Bus1LV2 (Nom. kV=0.4, Plot Ref. kV=0.4)
.5
1
3
5
10
30
50
100
300
500
1K
3K
5K
10K
1K
1K
500
Condenser Cleaning System
FLA
CableMCC1-1
Ampacity
300
500
9.02 Amps
300
59.7 Amps
Relay4 - P
OC1
Siemens
3VF3 (Fixed)
Size = 16 Amps
Thermal Trip = Fixed
Magnetic Trip = Fixed
50
30
CB1LV9
Siemens
7SJ80
CT Ratio 630:1
IEC - Long Inverse
Pickup = 0.8 (0.1 - 4 Sec - 1A)
Time Dial = 0.1
3x = 6 s, 5x = 3 s, 8x = 1.71 s
Inst = 5.1 (0.1 - 35 Sec - 1A)
Time Delay = 0.2 s
CBMCC1-1
100
100
50
±
R
30
Relay4
10
10
5
5
CableMCC1-1 - P
1 - 4/C 16 mm²
Copper XLPE
Tc = 90C
Plotted - 1 x 16 mm²
3
3
1
.5
.5
.3
.3
.1
.1
.05
.05
.03
.03
.01
.5
1
3
5
10
30
50
100
300
500
1K
Amps X 10 Bus1LV2 (Nom. kV=0.4, Plot Ref. kV=0.4)
Project:
Location:
Contract:
Engineer:
Filename:
Timor-1 CFSPP Project
Kupang, NTT, Indonesia
0389.PJ/DAN.02.01/010000/2019
YHN
D:\File Penting Nafis\Kerja Bismillah !!\PLN - gawe\Koordinasi Proteksi Relay PLT
Date: 09-05-2022
SN:
Rev: Base
Fault: Phase
3K
5K
.01
10K
ETAP Star 19.0.1C
CBMCC1-1
CableMCC1-1
1-4/C 16
Condenser Cleaning System
6.25 kVA
1
Seconds
Seconds
LV-1AB MCC
Generator Protection Settings 7UM85
Timor-1
Coal Fired Steam Power Plant 2 X 50 MW
(Timor-1 CFSPP Project)
Consortium of
PT. IKPT - PT. PP (Persero) Tbk. - ITOCHU Corporation - Sumitomo
Heavy Industries, Ltd. - PT. Medco Power Indonesia
Log Date:
in Comm No:
CIVIL
PLN DOC. NO. :
MECH
B
APPROVED
APPROVED AS NOTED
REVIEW
ELECT
A
I&C
CONTRACTOR DOC. NO. :
SUPPORT
T1-IK-200-ELE-INF-00003-AXGI01
GENERAL
CONTRACT NO. :
0389.PJ/DAN.02.01/010000/2019
C
NOT APPROVED
Purchase Order Number:
I
INFORMATION
REVIEWED DOES NOT RELIEVE CONTRACTOR
FROM RESPONSIBILITY FOR ERROR OR
DEVIATIONS FROM CONTRACT REQUIREMENTS
By:
Date:
Date:
Log Comm
in No.
DISTRIBUTION
PLN UIP NUSRA (HO)
AC025800
Purchase Order Description: COMPLETE STEAM TURBINE GENERATOR
PLN UPP TIMOR
PLN PUSENLIS (JKT)
MR Number:
AXGI01
Vendor Docs Number: 0-76620-BB2284A-30
JAYA CM (JKT)
CONTRACTOR (JKT)
REV
B
Equipment Tag No:
VENDOR REVIEW CODE↓
Sta
Stts
Code Description
tus
Code
CONTRACTOR (SITE)
Note:
1
2
3
4
Z
APPROVED
APPROVED AS NOTED.
WORK MAY PROCEED SUBJECT TO INCORPORATON OF CHANGES INDICATED
NOT APPROVED.
TO BE REVISED & RESUBMITTED. WORK MAY NOT PROCEED
INFORMATION ONLY. REVIEW NOT REQUIRED.
WORK MAY PROCEED
CERTIFIED FINAL / AS BUILT / ACCEPTED AS FINAL
“Code 1”, “Code 2” and “Code Z” endorsed on Supplier data by CONSORTIUM and/or OWNER shall not relieve the
Supplier from full responsibility for any errors or omissions, therein, or limit the Supplier’s obligations for conformance
to Specification and Purchase Order or Contract requirements.
Reviewing Engineer's/PEM/PE/PIC/PM Name (IN BLOCK LETTERS), Sign and Date
Name:
Sign:
Date:
1
2021-04-15
Issued for information
Fiebig
Eidner
Eidner
0
2021-03-15
Issued for information
Fiebig
Eidner
Eidner
REV
DATE
PURPOSE OF ISSUE
PREPARED
CHECKED
APROVED
AUTHORIZED
based on Std. Rev. Q
Transmittal, reproduction, dissemination and/or editing of this document as well as utilization of its contents and communication thereof to
others without express authorization are prohibited. Offenders will be held liable for payment of damages. All rights created by patent grant or
registration of a utility model or design patent are reserved. Siemens restricted, Copyright (C) Siemens AG, 2013
ECCN : N
LKZ: DE
Goods labeled with "AL” not equal to "N” are subject to European or German export authorization when being exported out of the EU. Goods
labeled with "ECCN” not equal to “N" are subject to US reexport authorization. Even without a label, or with label "AL:N" or "ECCN:N",
authorization may be required due to the final end-use and destination for which the goods are to be used.
AL : N
Siemens Energy
Steam Turbine
B
A
-
-
Revision
Sheet
Klass.Nr.:
Dok.-Art:
Handling
2021-04-12
2021-03-12
Generator Protection Settings 7UM85
Timor
Fiebig
Fiebig
Date
prepared
for internal use only
Eidner
Eidner
reviewed
Voelkel
Eidner
released
Original of:
Rev.:
Format
Ident-Nummer/Unterlagen-Nummer
Revision
A4
0-76620-BB2284A-30
B
B
Short circuit power of the grid
First revision for 7UM85
Description of Change
Classifiction:
Language
INT
Sheet
EN 1/ 70
Contents
3
8
15
21
24
26
28
29
34
37
40
41
42
44
46
48
50
52
53
57
60
61
65
67
Input Data
Group Power System
Impedance Protection (ANSI 21)
Overexcitation Protection (ANSI 24)
Undervoltage Protection 3ph. (ANSI 27)
Reverse Power Protection (ANSI32R)
Turbine Overload Protection (ANSI 32T)
Underexcitation Protection (ANSI 40)
Unbalanced Load Protection (ANSI 46)
Thermal Over Load Protection (ANSI 49)
Definite Time Overcurrent Protection (I>>, ANSI 50)
Inadvertent Energization (ANSI 50/27)
Breaker Failure Protection (ANSI 50BF)
Sensitive Earth Fault Protection (ANSI 51GN)
Definite Time Overcurrent Protection (I>, ANSI 51V) with Undervoltage Seal-In
Inverse-Time Overcurrent Protection (ANSI 51V)
Overvoltage Protection (ANSI 59)
90% Stator Earth Fault Protection (ANSI 59N)
100% Stator Earth Fault Protection (ANSI 64G)
Rotor Earth Fault Protection R, fn (ANSI 64R)
Trip Circuit Supervision (ANSI 74TC)
Out-of-Step Protection (ANSI 78)
Frequency Protection (ANSI 81)
Differential Protection (ANSI 87G)
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
2 / 70
B
INT
Input Data
General Options
Connection to network
Unit
Type of starpoint earthing
Grounding Transformer
Differential protection zone
Generator
Protection redundancy
Yes
Excitation system
Rotating Rectifier
Generator rated power range
50 .. 200MVA
Connection of the CT's
Side 2
Side 1
G3~
CT
CT
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
3 / 70
B
INT
Input Data
Scope of Protection
Function
ANSI
Status
Impedance Protection
21
Enabled
Overexcitation Protection
24
Enabled
Undervoltage Protection 3ph.
27
Enabled
Reverse Power Protection
32R
Enabled
Turbine Overload Protection
32T
Enabled
Underexcitation Protection
40
Enabled
Unbalaced Load Protection
46
Enabled
Thermal Over Load Protection
49
Enabled
Definite-Time Overcurrent Prot. I>>
50
Enabled
Inadvertend Energization Protection
50/27
Enabled
Breaker Failure Protection
50BF
Enabled
Sensitive Earth Fault Protection
51GN
Enabled
Sensitive Earth Fault Protection REF
51GN
Disabled
Definite-Time Overcurrent Prot. I> + U<
51V
Enabled
Inverse-Time Overcurrent Protection
51V
Enabled
59
Enabled
90% Stator Earth Fault Protection
59N, 67G
Enabled
Sensitive Rotor Earth Fault 1-3Hz
64R
Disabled
100% Stator Earth Fault Protection
64G
Enabled
Rotor Earth Fault Protection R, fn
64R
Enabled
Power Swing Blocking
68
Disabled
Trip Circuit Supervision
74TC
Enabled
Out of Step Protection
78
Enabled
Frequency Protection
81
Enabled
81R
Disabled
87
Enabled
87TN
Disabled
Overvoltage Protection
Rate of Frequency Change Protection
Differential Protection
Earth Current Differential Protection
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
4 / 70
B
INT
Input Data
Current Transformers
Addr.
Parameter
Value
Unit
-
CT-starpoint Line side towards generator
YES
-
CT rated primary current Line side
4000
A
-
CT rated secondary current Line side
1
A
-
CT-starpoint Neutral side towards generator
YES
-
CT rated primary current Neutral side
4000
A
-
CT rated secondary current Neutral side
1
A
-
I-1 ph 1 CT rated primary current
200
A
-
I-1 ph 1 CT rated secondary
5
A
-
I-1 ph 2 CT rated primary current
1
A
-
I-1 ph 2 CT rated secondary
1
A
-
I-1 ph 3 CT rated primary current (spare)
-
A
-
I-1 ph 3 CT rated secondary (spare)
-
A
Value
Unit
15000
V
100
V
Voltage Transformers
Addr.
Parameter
-
V-3 ph 1 Rated primary voltage
-
V-3 ph 1 Rated secondary voltage (ph-ph)
-
V-1 ph 1 Rated primary voltage
8660.00
V
-
V-1 ph 1 Rated secondary voltage
200.00
V
-
V-1 ph 2 Rated primary voltage
220.00
V
-
V-1 ph 2 Rated secondary voltage
86.00
V
-
V-1 ph 3 Rated primary voltage (spare)
-
V
-
V-1 ph 3 Rated sec. voltage (spare)
-
V
-
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
5 / 70
B
INT
Input Data
Generator - General Data
Parameter
Addr.
Value
Unit
15000
V
-
Rated primary voltage generator
-
Positive nominal machine voltage tolerance
5
%
-
Negative nominal machine voltage tolerance
5
%
-
Rated apparent power of the generator
74.14
MVA
-
Power factor
0.85
-
-
Rated frequency
50
Hz
-
Sustained short circuit current
4300
A
-
P1/Q1 from Generator capability diagram
0.00
-0.49
p.u.
-
P2/Q2 from Generator capability diagram
0.44
-0.49
p.u.
-
P3/Q3 from Generator capability diagram
0.90
-0.44
p.u.
Generator - Thermal Settings
Parameter
Addr.
Value
Unit
-
Thermally continuous permissible current
2996
A
-
Permissable long term thermal inverse IMN
10
%
-
Asymmetry factor
10.00
s
-
Minimal thermal time constant
418
s
Value
Unit
Generator - Excitation Settings
Addr.
Parameter
-
Excitation voltage (no-load)
63
V
-
Excitation voltage (rated load)
163
V
-
Voltage divider transformation ratio
20
-
Generator - Reactances
Addr.
Parameter
Value
Unit
-
Direct-axis synchrounous reactance unsat. xd
189
%
-
Direct-axis synchrounous reactance sat. xd
170
%
-
Direct-axis transient reactance unsat. xd'
24.9
%
-
Direct-axis transient reactance sat. xd'
22.4
%
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
6 / 70
B
INT
Input Data
Neutral Grounding Transformer - Load Resistor
Parameter
Addr.
Value
Unit
-
Nominal earthing transformer voltage (prim)
-
Nominal earthing transformer voltage (sec)
500
V
-
Overload capacity of earthing transformer
10
s
-
Resistance of load resistor
5.00
Ω
-
Short Time load resistor current (t Load)
100
A
-
Overload capacity of load resistor
10
s
Value
Unit
15000 / √3
V
Unit Transformer
Parameter
Addr.
-
Nominal transformer voltage (gen. side)
15000
V
-
Nominal transformer voltage (grid side)
150000
V
-
Rated apparent power of the transformer
73
MVA
-
Transformer short-circuit-ratio usc
13
%
-
Transformer reactance on gen. MVA base
0.132
p.u.
Value
Unit
2650
MVA
Grid Data
Parameter
Addr.
-
Rated short circuit power of the grid
-
Nominal grid voltage
150000
V
-
Grid reactance on generator MVA base
0.0303
p.u.
-
Grid R/X ratio
0.125
p.u.
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
B
7 / 70
B
INT
Group Power System
General
At each third measurement input, a second phase-to-phase voltage (voltage VBC) is connected which
— together with each first voltage allows the phase sequence to be checked - with parameter .101
Phase sequence .
Address
Parameter
.101
Phase sequence
Setting Options
Presetting
Value
(secondary)
Comments
ABC
ABC
Phase sequence check
ABC
ACB
Meas. Point I-3 ph 1 (Line side)
At address .101 Rated primary current , the primary current of CT of side 1 is entered for correct
primary representation of the measured values. Address .102 Rated secondary current represents
the secondary current of CT of side 1. The best sampling frequency of measuring point will be adjusted
if parameter .127 Tracking = active. The direction of neutral point of CT must be set in parameter .116
Neutr.point in dir of ref obj. Inverted phases parameter .114 Inverted phases is used for special
application only.
Magnitude correction for CT1, CT2 and CT3 can be done for highly precise measurements only via
.103 Magnitude correction parameter. Connected phase is shown via .117 Phase parameter for
CT1, CT2 and CT3 according Measuring points routing.
Setting Options
Presetting
Value
(secondary)
Comments
active
active
Active tracking recommended
Address
Parameter
.127
Tracking
.101
Rated primary
current
1.0…100000.0 A
1000.0 A
.102
Rated secondary
current
1 or 5 A
.116
Neutr.point in dir.
of ref. obj
.114
Inverted phase
active
inactive
yes
no
none
AC/BC/AB
4000.0 A
Rated primary current of CT
1A
1 A
Rated secondary current of
CT
yes
yes
Direction of neutral point of CT in
direction of reference object
none
none
No inverted phase for current
measurement
active
active
Active tracking recommended
MP disconnection
.173
Current check
.112
I<threshold
active
inactive
10.0
%
secondary
percent
10.0 %
0.100
A
primary
400.0
A
Min threshold for current check
function
CT1
.103
Magnitude
correction
0.010…10.000
1
1.000
.117
Phase
IA
IA
IA
Ident-No.
For corrections for highly
precise measurements only.
Connected phase
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
8 / 70
B
INT
CT2
Value
(secondary)
Address
Parameter
Setting Options
Presetting
.103
Magnitude
correction
0.010…10.000
1
1.000
.117
Phase
IB
IB
IB
.103
Magnitude
correction
0.010…10.000
1
1.000
.117
Phase
IC
IC
IC
Comments
For corrections for highly
precise measurements only.
Connected phase
CT3
For corrections for highly
precise measurements only.
Connected phase
Supv. balan. I
.1
Mode
.101
Release threshold
on
off
percent
off
50.0 %
Activation of Current-balance
supervision
off
50.0
%
secondary
0.500
A
primary
2000.0
A
.102
Threshold
min/max
0.10 … 0.95
0.50
.6
Delay failure
indication
0.00…100.00 s
5.00 s
Min threshold for magnitude
supervision function
0.50
Magnitude supervision
function
5.00 s
Time delay before failure of Subv.
balan. I will be indicated.
Supv. ph. Seq. I
on
Mode
.6
Delay failure
indication
0.00…100.00 s
5.00 s
percent
50.000 %
50.0
%
.102
Release threshold
secondary
0.500
A
primary
2000.0
A
off
off
Enable Phase rotation
supervision.
.1
on
Time delay before failure of phase
sequence will be indicated.
5.00 s
Min threshold for magnitude
supervision function
Meas. Point I-3 ph 2 (Neutral side)
Setting Options
Presetting
Value
(secondary)
Comments
active
active
Active tracking recommended
Address
Parameter
.127
Tracking
.101
Rated primary
current
1.0…100000.0 A
1000.0 A
.102
Rated secondary
current
1 or 5 A
.116
Neutr.point in dir.
of ref. obj
.114
Inverted phase
active
inactive
yes
no
none
AC/BC/AB
4000.0 A
Rated primary current of CT
1A
1 A
Rated secondary current of
CT
yes
yes
Direction of neutral point of CT in
direction of reference object
none
none
No inverted phase for current
measurement
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
9 / 70
B
INT
MP disconnection
.173
Current check
active
inactive
I<threshold
active
Active tracking recommended
10.0
%
secondary
0.100
A
primary
400.0
A
percent
.112
active
10.0 %
Min threshold for current check
function
CT1
.103
Magnitude
correction
0.010…10.000
1
1.000
.117
Phase
IA
IA
IA
.103
Magnitude
correction
0.010…10.000
1
1.000
.117
Phase
IB
IB
IB
.103
Magnitude
correction
0.010…10.000
1
1.000
.117
Phase
IC
IC
IC
For corrections for highly
precise measurements only.
Connected phase
CT2
For corrections for highly
precise measurements only.
Connected phase
CT3
For corrections for highly
precise measurements only.
Connected phase
Supv. balan. I
.1
Mode
on
off
percent
.101
Release threshold
off
50.0 %
Activation of Current-balance
supervision
off
50.0
%
secondary
0.500
A
primary
2000.0
A
.102
Threshold
min/max
0.10 … 0.95
0.50
.6
Delay failure
indication
0.00…100.00 s
5.00 s
Setting Options
Presetting
Value
(secondary)
off
on
Min threshold for magnitude
supervision function
0.50
Magnitude supervision
function
5.00 s
Time delay before failure of Subv.
balan. I will be indicated.
Supv. ph. Seq. I
Address
Parameter
.1
Mode
.6
Delay failure
indication
.102
Release threshold
on
off
0.00…100.00 s
5.00 s
percent
50.000 %
Comments
Enable Phase rotation
supervision.
Time delay before failure of phase
sequence will be indicated.
5.00 s
50.0
%
secondary
0.500
A
primary
2000.0
A
Ident-No.
Min threshold for magnitude
supervision function
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
10 / 70
B
INT
Meas. Point I-1 ph 1
At address .101 Rated primary current , the primary current of CT of side 1 is entered for correct
primary representation of the measured values. Address .102 Rated secondary current represents
the secondary current of CT of side 1. The best sampling frequency of measuring point will be adjusted
if parameter .127 Tracking = active. The direction of neutral point of CT must be set in parameter .116
Term. 1,3,5,7 in dir. of obj.
Magnitude correction for CT1, CT2 and CT3 can be done for highly precise measurements only via
.103 Magnitude correction parameter. Connected phase is shown via .117 Phase parameter for
CT1, CT2 and CT3 according Measuring points routing.
Address
Parameter
Setting Options
Presetting
.101
Rated primary
current
1.0…100000.0 A
1000.0 A
.102
Rated secondary
current
1 or 5 A
.116
Term.1,3,5,7 in
dir. of obj
.105
Tracking
yes
no
active
inactive
Value
(secondary)
Comments
200.0 A
Rated primary current of CT
1A
5 A
Rated secondary current of
CT
yes
yes
Direction of neutral point of CT in
direction of reference object
active
active
Active tracking recommended
CT1
.103
Magnitude
correction
0.010…10.000
1
1.000
.117
Phase
IA
IA
IA
For corrections for highly
precise measurements only.
Connected phase
Meas. Point I-1 ph 2
Address
Parameter
Setting Options
Presetting
.101
Rated primary
current
1.0…100000.0 A
1000.0 A
.102
Rated secondary
current
1 or 5 A
.116
Term.1,3,5,7 in
dir. of obj
.105
Tracking
yes
no
active
inactive
Value
(secondary)
Comments
1.0 A
Rated primary current of CT
1A
1 A
Rated secondary current of
CT
yes
yes
Direction of neutral point of CT in
direction of reference object
active
active
Active tracking recommended
CT1
.103
Magnitude
correction
0.010…10.000
1
1.000
.117
Phase
IA
IA
IA
Ident-No.
For corrections for highly
precise measurements only.
Connected phase
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
11 / 70
B
INT
Meas. Point V-3 ph 1
At address .101 Rated primary voltage , the primary transformer rated voltage of 3 phase voltage
transformer is entered for correct primary representation of the measured values. Address .102 Rated
secondary voltage represents the secondary VT rated voltage. Parameter .106 Inverted phases is
used for special application only. The best sampling frequency of measuring point will be adjusted if
parameter .111 Tracking = active. Magnitude correction for VT1 and VT2 can be done for highly
precise measurements only via .103 Magnitude correction parameter. Connected phase needs to be
selected within measuring point routing and can be checked via .108 Phase parameter. Phase rotation
supervision can be enabled via parameter .1 Mode and the time delay before indication can be
changed with parameter .6 Delay failure indication .
Value
(secondary)
Address
Parameter
Setting Options
Presetting
.101
Rated
primary voltage
0.20…1200.000 kV
400 kV
.102
Rated
secondary voltage
80…230 V
100 V
100 V
.106
Inverted phase
none
none
No inverted phase for voltage
measurement
.111
Tracking
active
active
Active tracking recommended
none
AC/BC/AB
active
inactive
Comments
15.000 kV
Rated primary voltage of VT
Rated Secondary
Voltage of VT
VT1
.103
Magnitude
correction
0.010…10.000
1
1.000
For corrections for highly
precise measurements only.
.108
Phase
VA
VA
VA
Connected phase to be selected
.103
Magnitude
correction
0.010…10.000
1
1.000
For corrections for highly
precise measurements only.
.108
Phase
VB
VB
VB
Connected phase to be selected
.103
Magnitude
correction
0.010…10.000
1
1.000
For corrections for highly
precise measurements only.
.108
Phase
VC
VC
VC
Connected phase to be selected
VT2
VT3
Supv. balan. V
.1
Mode
.101
Release threshold
on
off
percent
off
50.0 %
Activation of Voltage-balance
supervision
off
50.0
%
secondary
50.000
V
primary
7.500
kV
.102
Threshold
min/max
0.58…0.95
0.75
.6
Delay failure
indication
0.00…100.00 s
5.00 s
Min threshold for magnitude
supervision function
0.75
Magnitude supervision
function
5.00 s
Time delay before failure of Subv.
balan. V will be indicated.
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
12 / 70
B
INT
Meas. Point V-3 ph 1
Supv. Ph. Seq. V
.1
Mode
.6
Delay failure
indication
on
off
0.00…100.00 s
off
5.00 s
Enable Phase rotation
supervision.
off
Time delay before failure of phase
sequence will be indicated.
5.00 s
Supv. sum V
.1
Mode
.101
Tthreshold
.6
Delay failure
indication
on
off
off
Activation of Voltage-sum
supervision
off
percent
25.0
%
secondary
14.434
V
primary
2.165
kV
Min Threshold for Voltage-sum
supervision
0.00…100.00 s
5.00 s
5.00 s
Time delay before failure of voltagesum will be indicated.
0.00…0.03 s
0.00 s
0.02 s
Response time for VT miniature CB
VT miniature CB
.101
Response time
Meas. Point V-1 ph 1
At address .101 Rated primary voltage , the primary transformer rated voltage of 1 phase voltage
transformer is entered for correct primary representation of the measured values. Address .102 Rated
secondary voltage represents the secondary VT rated voltage.
Parameter .103 Tracking = inactive for 1 phase voltage transformers. Magnitude correction for VT1
can be done for highly precise measurements only via .103 Magnitude correction parameter.
Connected phase needs to be selected within measuring point routing and can be checked via .108
Phase parameter.
Value
(secondary)
Comments
Address
Parameter
Setting Options
Presetting
.101
Rated
primary voltage
0.20…1200.00 kV
400 kV
8.660 kV
Rated primary voltage of VT
.102
Rated secondary
voltage
80…230 V
100 V
200 V
Rated Secondary
Voltage of VT
.103
Tracking
active
inactive
active
active
Active tracking recommended
VT1
.103
Magnitude
correction
0.010…10.000
1
1.000
For corrections for highly
precise measurements only.
.108
Phase
VX
VX
VX
Connected phase to be selected
0.00…0.03 s
0.00 s
0.00 s
Response time for VT miniature CB
VT miniature CB
.101
Response time
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
13 / 70
B
INT
Meas. Point V-1 ph 2
At address .101 Rated primary voltage , the primary transformer rated voltage of 1 phase voltage
transformer is entered for correct primary representation of the measured values. Address .102 Rated
secondary voltage represents the secondary VT rated voltage.
Parameter .103 Tracking = inactive for 1 phase voltage transformers. Magnitude correction for VT1
can be done for highly precise measurements only via .103 Magnitude correction parameter.
Connected phase needs to be selected within measuring point routing and can be checked via .108
Phase parameter.
Value
(secondary)
Address
Parameter
Setting Options
Presetting
.101
Rated
primary voltage
0.20…1200.00 kV
400 kV
.102
Rated secondary
voltage
80…230 V
100 V
86 V
Rated Secondary
Voltage of VT
.103
Tracking
active
active
Active tracking recommended
active
inactive
0.220 kV
Comments
Rated primary voltage of VT
VT1
.103
Magnitude
correction
0.010…10.000
1
1.000
For corrections for highly
precise measurements only.
.108
Phase
VX
VX
VX
Connected phase to be selected
0.00…0.03 s
0.00 s
0.00 s
Response time for VT miniature CB
VT miniature CB
.101
Response time
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
14 / 70
B
INT
Impedance Protection (ANSI 21)
Machine impedance protection is used as a selective time graded protection to provide the shortest
possible tripping times for short-circuits in the synchronous machine, on the terminal leads as well as in
the unit transformer. It thus also provides backup protection functions to the main protection of a power
plant or protection equipment connected in series like generator, transformer differential and system
protection devices.
Functional Description
PICKUP
Pickup is required to detect a faulty condition in the power system and to initiate all the necessary
procedures for selective clarification of the fault:
- Start the time relays for the final stage
- Determination for the faulty measuring loop
- Enabling of impedance calcualtion
- Indication/output of the faulty conductor(s).
Undervoltage Seal-In
With excitation systems powered from the network, excitation voltage can drop during a local short
circuit, resulting in decreasing short-circuit current which, in spite of the remaining fault, can undershoot
the pickup value. In such cases the impedance protection pick-up is maintained for a sufficiently long
period by means of an undervoltage controlled seal-in circuit using the positive sequence voltage U1.
Tripping Characteristic
The tripping characteristic of the impedance protection is a polygon. As long as the pickup criteria are
met, impedance calculation is done continuously using the current and voltage vectors derived from the
loop selection measured values. If the calculated impedance is within the tripping characteristic, the
protection sends a tripping command according to the specified delay time.
Since the impedance protection is multi-stage, the protected zones can be chosen such that the first
stage (ZONE TZ 1) covers faults in the generator and the lower voltage side of the unit transformer.
The ZONE TZ 2(B) is used in case of open Unit CB as a short time trip because a detected fault in this
zone must be on HV side of the unit transformer before the Unit CB.
The Zone TZ 3 must be coordinatied with the 1. zone of the distance protection in the electrical power
system.
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
15 / 70
B
INT
Impedance Protection (ANSI 21)
Settings
Symbol
UNM
Value
Comments
15.00
kV
Nominal machine voltage
INM
2854
A
Nominal machine current
UNT
15.00
kV
Nominal transformer voltage (machine side)
SNT
73
MVA
Nominal transformer apparent power
uSC
13.0
%
Relative transformer short-circuit-voltage
kRZ1
70
%
Protection zone 1 reach
kRZ2B
110
%
Protection zone 2B reach
kRZ3
100
%
Protection zone 3 reach
Ratio VT
15000
V
100
V Ratio of voltage transformer
Ratio CT
4000
A
1
A Ratio of current transformer
ΔUNM-
5
%
Negative nominal machine voltage tolerance
PICKUP
The maximum load current during operation is the most important criterion for setting overcurrent
pickup. A pickup by an overload must be excluded! For this reason, the .104 Overcurrent Threshold
pickup value must be set above the maximum (over) load current to be expected. Adequate setting:
120% of the maximum permissible continuous generator current (at minimum continuous permissible
voltage tolerance of generator). The pickup logic corresponds to the logic of the UMZ I> definite timeovercurrent protection.
i>
Overcurrent
threshold
105
100
= 1.26
* INM *
IN CT sec
IN CT prim
= 1.20 *
=
i>
= 1.26 * 2854
A *
1
4000
Ident-No.
A
A
=
0.90
0-76620-BB2284A-30
A
Sheet
Blatt
Revision
Classification
16 / 70
B
INT
Impedance Protection (ANSI 21)
If the excitation is derived from the generator terminals with the short circuit current possibly falling
below the pickup value .106 V-seal-in theshold due to the collapsing voltage, the undervoltage seal-in
feature of the pickup is used, i.e. address .105 Undervoltage seal in is switched to yes.
The undervoltage seal-in setting .106 V-seal-in theshold is set to a value just below the lowest phaseto-phase voltage occurring during operation, e.g. = 70 % of the nominal voltage. The seal-in time .107
Duration of V-seal-in time must exceed the maximum fault clearance time in a back-up case
(recommended 4 s ).
V-seal-in
theshold
=
0.80
*
UN VT sec
√3
=
0.80 * 100 V
√3
V
=
46.2
V
Impedance Stages
The protection has the following characteristics which may be set independently:
1. Zone (fast tripping zone TZ 1) with parameters
ZONE TZ1 … Reactance = reach,
TZ 1
… = 0,3 s
Therefore ZONE TZ 1 is normally set to a reach of approx. 70 - 90 % of the protected zone (i.e. about
70 - 90 % of the transformer reactance), with short time delay (TZ 1 = 0.3 s). Protection then covers
faults on this distance after its operating time. If a tap changer is available, the fault impedance
changes with the tap position - thus for the safe side the setting range of 70 % shall be implemented.
2. Overeach zone TZ 2(B), externally controlled via binary input with parameters
ZONE TZ 2(B) ... Reactance = reach,
TZ 2(B)
... = 0,3 s
For ZONE TZ 2(B) the reach can be set from 110 % to 200 % of the transformer reactance. Standard
setting value will be 110 %. During commissioning this value will be measured exactly and setting shall
be revised accordingly. The corresponding ZONE TZ 2(B) time stage is set to 0.3 sec.
3. Zone (fast tripping zone TZ 3) with parameters
ZONE TZ3 … Reactance = reach,
TZ 3
… = 0,5 s
For ZONE TZ 3 the reach is set to 100 % of the transformer reactance. The corresponding ZONE TZ 3
time stage is set to 0.5 sec.
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
17 / 70
B
INT
Impedance Protection (ANSI 21)
Recommendation for Impedance setup:
4000 A
=
1
A
CT ratio:
X/R1prim
uSC
=
100%
*
4000
UNT²
SNT
kR Z1
*
15000 V
100 V
VT ratio:
100%
/ √3
=
/ √3
150
=
( 15.00 kV )²
70 %
13.0 %
*
*
100%
73
MVA
100 %
=
0.2805
Ω
X/R2Bprim =
uSC
UNT²
*
100%
SNT
*
kR Z2B
100%
=
(
13.0 %
*
100%
15
73
kV )² 110 %
*
MVA
100 %
=
0.4408
Ω
X/R3prim
=
uSC
UNT²
*
100%
SNT
*
kR Z2
100%
=
(
13.0 %
*
100%
15
73
kV )² 100 %
*
MVA
100 %
=
0.4007
Ω
X/R1sec
= Z1prim *
üCT
üVT
=
0.2805
Ω *
4000
150
=
7.48
Ω
X/R2Bsec = Z1Bprim*
üCT
üVT
=
0.4408
Ω *
4000
150
=
11.75
Ω
= Z2prim *
üCT
üVT
= 0.40068 Ω *
4000
150
=
10.68
Ω
X/R3sec
Recommendation for R/X-ratio:
R/Xratio
=
1
2
=
0.50
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
18 / 70
B
INT
Impedance Protection (ANSI 21)
General
Address
Parameter
.1
Mode
.102
Loop selection
.104
Overcurrent
Threshold
Setting Options
on
off / test
Current-dependent
All loops
Presetting
Values
Comments
on
on
Stage must be activated
All loops
Current-dependent
Current dependent recommended
percent
secondary
1.3 A
primary
yes
126.00
%
0.90
A
3595.60
A
Threshold for current criterion
.105
Undervoltage seal
in
.106
V-seal-in
threshold
secondary
Duration of V-seal-in
0.00 … 60.00 s
4.00 s
Address
Parameter
Setting Options
Presetting
Values
Comments
.1
Mode
on
on
TZ 1 stage must be activated
.2
Operate & flt.rec.
blocked
yes
no
no
If yes - TZ 1 stage has reporting
effect only.
percent
70 %
.102
X reach (ph-g)
secondary
2.5 Ω
.107
no
no
percent
yes
Stage must be activated
80.0
46.2 V
primary
%
46.19
V
6.928
kV
4.00
s
Threshold for V-seal-in criterion
T U< Time Delay
TZ 1
on
off / test
no
primary
.103
X reach (ph-ph)
R reach (ph-g)
70 %
secondary
2.5 Ω
35 %
secondary
2.5 Ω
R reach (ph-ph)
percent
35 %
secondary
2.5 Ω
primary
.109
Directional mode
.6
Operate delay
non-directional
forward / reverse
0.00 … 60.00; ∞ s
reverse
0.30 s
Impedance Zone TZ 1 X
Ω
%
7.479
Ω
0.280
percent
primary
.105
Ω
0.280
percent
primary
.104
%
7.479
Impedance Zone TZ 1 X
Ω
%
3.740
Ω
0.140
Ω
Impedance Zone TZ 1 R
%
3.740
Ω
0.140
Ω
For generator applications nondirectional must be selected
non-directional
0.30
s
Ident-No.
Impedance Zone TZ 1 R
TZ 1Time Delay
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
19 / 70
B
INT
Impedance Protection (ANSI 21)
TZ 2 (B)
Address
Parameter
.1
Mode
.2
Operate & flt.rec.
blocked
.102
X reach (ph-g)
Setting Options
on
off / test
yes
no
Presetting
Values
Comments
on
on
TZ 2 (B) stage must be activated
no
no
If yes - TZ 2 (B) stage has
reporting effect only.
percent
110 %
secondary
2.5 Ω
primary
.103
X reach (ph-ph)
percent
110 %
secondary
2.5 Ω
primary
.104
R reach (ph-g)
percent
55 %
secondary
2.5 Ω
primary
.105
R reach (ph-ph)
11.75
Ω
0.441
Ω
55 %
secondary
2.5 Ω
primary
Ω
0.441
Ω
Impedance Zone TZ 2 (B) X
%
5.88
Ω
Impedance Zone TZ 2 (B) R
Ω
%
5.88
Ω
0.220
Ω
Impedance Zone TZ 2 (B) R
For generator applications nondirectional must be selected
.109
Directional mode
.6
Operate delay
0.00 … 60.00; ∞ s
0.30 s
Address
Parameter
Setting Options
Presetting
Values
Comments
.1
Mode
on
off
TZ 3 stage may be activated on
grid request
.2
Operate & flt.rec.
blocked
no
no
If yes - TZ 3 stage has reporting
effect only.
forward / reverse
reverse
Impedance Zone TZ 2 (B) X
%
11.75
0.220
percent
non-directional
%
non-directional
0.30
s
TZ 2 (B)Time Delay
TZ 3
.102
X reach (ph-g)
on
off / test
yes
no
percent
100 %
secondary
2.5 Ω
primary
.103
X reach (ph-ph)
percent
100 %
secondary
2.5 Ω
primary
.104
R reach (ph-g)
percent
50 %
secondary
2.5 Ω
primary
.105
R reach (ph-ph)
50 %
secondary
2.5 Ω
primary
.109
Directional mode
.6
Operate delay
forward / reverse
0.00 … 60.00; ∞ s
10.68
Ω
0.401
Ω
reverse
0.30 s
Impedance Zone TZ 3 X
%
10.68
Ω
0.401
Ω
Impedance Zone TZ 3 X
%
5.34
Ω
0.200
percent
non-directional
%
Impedance Zone TZ 3 R
Ω
%
5.34
Ω
0.200
Ω
For generator applications nondirectional must be selected
non-directional
0.50
s
Ident-No.
Impedance Zone TZ 3 R
TZ 3 Time Delay
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
20 / 70
B
INT
Overexcitation Protection (ANSI 24)
Overexcitation protection is used to detect inadmissibly high induction in generators and transformers,
especially in power station unit transformers. The protection must intervene when the limit value for the
protected object (e.g. unit transformer) is exceeded. The transformer is endangered, for example, if the
power station block is disconnected from the system from full-load, and if the voltage regulator either
does not operate or does not operate sufficiently fast to control the associated voltage rise. Similarly a
decrease in frequency (speed), e.g. in island systems, can lead to an inadmissible increase in
induction.
Functional Description
The overexcitation protection feature servers to measure the U/f voltage / frequency ratio, which is
proportional to the induction (B) and puts it in relation to the nominal induction (BN). In this context, both
voltage and frequency are related to nominal values of the object to be protected (generator,
transformer).
B
~
U
f
B
BNM
U
UNM
~
f
fN
=
U
f
Overexcitation protection includes two staged characteristics and one thermal characteristic for
approximate modeling of the heating of the protection object due to overexcitation. As soon as a first
pickup threshold (Thermal stage U/f >) has been exceeded, a warning delay time is started. On its
expiry a warning message is transmitted. At the same time an integrator is activated when the pickup
threshold is exceeded. This weighted counter is incremented in accordance with the current U/f value
resulting in the trip time for the parametrized characteristic. A trip signal is transmitted as soon as the
trip counter state has been reached.
The trip signal is retracted as soon as the value falls below the pickup threshold and the counter is
decremented in accordance with a parametrizable cool-down time.
The thermal U/f characteristic of the generator is specified by 8 value pairs for overexcitation U/f
(related to nominal values) and trip time t.
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
21 / 70
B
INT
Overexcitation Protection (ANSI 24)
Settings
The limit-value setting at address . 3 Threshold thermal stage U/f > is based on the induction limit
value relation to the nominal induction (B/BN) as specified by the generator manufacturer. A pickup
message is transmitted as soon as the induction limit value U/f > set at address .3 Threshold thermal
stage is exceeded. A warning message is transmitted after expiry of the corresponding .103 Warning
delay . The .3 Threshold U/f >> trip stage characteristic serves to fast trip particularly strong
overexcitations if .6 Operate delay is expired.
A thermal characteristic is superimposed on the trip stage characteristic. For this purpose, the
temperature rise created by the overexcitation is approximately modeled. Not only the already
mentioned pickup signal is generated on exceedance of the U/f induction limit set at address .3
Threshold U/f < thermal stage, but in addition a counter is activated additionally which causes the
tripping after a length of time corresponding to the set characteristic (see following diagram).
10000
Duration Generator
Duration AVR-Limiter
Duration Protection
1000
not permitted
permitted
100
10
1
1.00
1.10
1.20
1.30
1.40
1.50
The trip times t of the overexcitation values U/f = 1.05; 1.10; 1.15; 1.20; 1.25; 1.30; 1.35 and 1.40 are
read out from the generator data sheet referred to as "short time voltage/frequency capability" and
entered at the addresses .108 Operate char. curve t(U/f=1.05) to t(U/f=1.40) with an offset of + 2% of
the time independent U/f. The protection device interpolates linearly between the points.
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
22 / 70
B
INT
Overexitation Protection (ANSI 24)
U/f >>
Address
Parameter
Setting Options
Presetting
Values
Comments
.1
Mode
on
on
U/f >> stage must be activated
.2
Operate & flt.rec.
blocked
yes
no
no
If yes - stage has reporting effect
only.
.3
Threshold
1.00 …1.40
1.40
1.40
.6
Operate delay
0.00 … 60.00 s
1.00 s
3.00
Setting Options
Presetting
Values
Comments
on
on
U< stage must be activated
no
no
If yes - stage has reporting effect
only.
on
off / test
no
U/f >> Threshold
s
U/f >> Operate Time delay
Therm. stage
Address
Parameter
.1
Mode
.2
Operate & flt.rec.
blocked
on
off / test
yes
no
.3
Threshold
1.00 …1.20
1.10
1.07
.101
Warning delay
0.00 … 60.00 s
10.00 s
10.00
s
Thermal stage warning delay
.102
Cooling time replica
0 … 100 000 s
3600 s
3600
s
Cooling time thermal replica
Operate curve
.108
Operate
char. curve
Thermal stage Threshold
8
No. of points
t(U/f = 1.05)
1300
s
U/f = 1.05 Time Delay
t(U/f = 1.10)
640
s
U/f = 1.10 Time Delay
t(U/f = 1.15)
270
s
U/f = 1.15 Time Delay
t(U/f = 1.20)
125
s
U/f = 1.20 Time Delay
t(U/f = 1.25)
52
s
U/f = 1.25 Time Delay
t(U/f = 1.30)
24
s
U/f = 1.30 Time Delay
t(U/f = 1.35)
11
s
U/f = 1.35 Time Delay
t(U/f = 1.40)
5
s
U/f = 1.40 Time Delay
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
23 / 70
B
INT
Undervoltage Protection 3ph. (ANSI 27)
The undervoltage protection function detects voltage dips on electrical machines and prevents
inadmissible operating states and a possible loss of stability. Two-pole short circuits or ground faults
cause a dip in asymmetrical voltages.
Functional Description
Undervoltage protection consists of up to three stages definite-time and two stages inverse-time. Two
stages definite-time undervoltage protection will be used. A pickup is signalled as soon as selectable
voltage threshold parameters .3 Threshold are undershot. A trip signal is transmitted if a voltage
pickup exists for a selectable time according parameters .6 Operate delay.
The drop-out ratio can be adapted in small steps to the operating conditions at address .4 Dropout
ratio . Default setting is 1.05.
Parameter .6 Operate delay for U< stage is set to 6s. This ensures that voltage dips which would
affect operating stability are disconnected. On the other hand, the time delay is large enough to avoid
disconnections during admissible short-time voltage dips.
In order to ensure that the protection does not accidentally pick up due to a secondary voltage failure,
each stage can be blocked individually or both stages together, via binary input(s), e.g. using a voltage
transformer miniature circuit breaker. Also the integrated Fuse-Failure Monitor will block the two stages
as well as the .104 current-flow criterion .
Settings
Symbol
UNM
Value
15.00
kV
Nominal machine voltage
INM
2854
A
Nominal machine current
Ratio VT
15000
Ratio CT
4000
Threshold I>
V
A
Comments
100
1
= 0.05 *
V Ratio of voltage transformer
A
Ratio of current transformer
INM
2854
* IN CT sec = 0.05 *
IN CT prim
4000
A
* 1
A
A
=
0.04
A
(secondary)
The pickup value of U< will be set to 70% and U<< to 60% of nominal machine voltage.
U< stage
=
0.70 * UNM * UN VT sec
UN VT prim
=
0.70 * 15.00 kV * 100 V
= 70.0 V
15
kV
(secondary)
U<< stage
=
0.60 * UNM * UN VT sec
UN VT prim
=
0.60 * 15.00 kV * 100 V
= 60.0 V
15
kV
(secondary)
General
Address
Parameter
Setting Options
.104
Current-flow
criterion
off
.101
Threshold I>
secondary
.103
Stabilization counter
on
percent
Presetting
Values
Comments
on
on
Current-flow criterion
recommended
5%
primary
0…10
0
5.00
%
0.036
A
143
A
0
Threshold for current criterion
Recommendation = 0
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
24 / 70
B
INT
U< stage
Address
Parameter
Setting Options
.1
Mode
.2
Operate & flt.rec.
blocked
yes
.10
Blk. by meas.-volt.
failure
yes
.9
Measured value
.8
Method of
measurement
.101
Pickup mode
.102
Pickup delay
on
off / test
no
no
ph-gnd
ph-ph
fundamental
RMS
1oo(3)
3oo(3)
yes
no
percent
.3
Threshold
Presetting
Values
Comments
on
on
U< stage must be activated
no
no
If yes - U< stage has reporting
effect only.
yes
yes
If measuring-voltage failure
detected U< stage will be blocked
ph-ph
ph-ph
Phase - Phase voltage will be
measured
fundamental
fundamental
Harmonics or transient voltage
peaks will be suppressed
1oo(3)
1oo(3)
U< pickup if 1 out of 3 voltages are
below Threshold.
yes
yes
Pickup delay used for current-flow
criterion if GCB opens.
80 %
70
%
secondary
70.00
V
primary
10.500
kV
Threshold for U< criterion
.4
Dropout ratio
1.01 …1.20
1.05
1.05
.6
Operate delay
0.00 … 60.00 s
3.00 s
6.00
Setting Options
Presetting
Values
Comments
on
on
U<< stage recommended
no
no
If yes - U<< stage has reporting
effect only.
yes
yes
If measuring-voltage failure
detected U<< stage will be blocked
ph-ph
ph-ph
Phase - Phase voltage will be
measured
fundamental
fundamental
Harmonics or transient voltage
peaks will be suppressed
1oo(3)
1oo(3)
U<< pickup if 1 out of 3 voltages
are below Threshold.
yes
yes
Pickup delay used for current-flow
criterion if GCB opens.
U< Drop out ratio
s
T U< Time Delay
U<< stage
Address
Parameter
.1
Mode
.2
Operate & flt.rec.
blocked
yes
.10
Blk. by meas.-volt.
failure
yes
.9
Measured value
.8
Method of
measurement
.101
Pickup mode
.102
Pickup delay
.3
Threshold
secondary
.4
Dropout ratio
1.01 …1.20
1.05
1.05
.6
Operate delay
0.00 … 60.00 s
3.00 s
1.00
on
off / test
no
no
ph-gnd
ph-ph
fundamental
RMS
1oo(3)
3oo(3)
yes
no
percent
80 %
primary
60
%
60.00
V
9.000
kV
Threshold for U<< criterion
U<< Drop out ratio
s
Ident-No.
T U<< Time Delay
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
25 / 70
B
INT
Reverse Power Protection (ANSI32R)
Reverse power protection is used to protect the turbine when the synchronous generator runs as a
motor and drives the turbine taking motoring energy from the grid. This condition leads to overheating
of the turbine blades and must be interrupted within a short time by opening the generator circuitbreaker. It is established operational practice to always shut down the steam turbine unit by using the
reverse power protection function. As soon as active power is taken from the grid the disconnection is
performed. This proves the ability of the steam valves to separate the turbine from its steam source
completely.
Functional Description
The reverse power protection of the 7UM85 precisely calculates the active power from the symmetrical
components of the fundamental waves of voltages and currents by averaging the values of the last 16
cycles. The evaluation of only the positive phase-sequence systems makes the reverse power
determination independent of current and voltage asymmetries and corresponds to the actual load.
Settings
The level of the active power input is determined by the friction losses to be overcome and is in the
following range:
Steam turbines: PReverse/SNM ≈ 1 % to 3 %
For the primary test, the reverse power should be measured during commissioning with the actual
protection device. The pickup value P> REVERSE for the reverse power protection must be set to 50%
of the measured value during test.
The pickup value P> REVERSE paramerter .3 Threshold is set in percent of the secondary apparent
power rating SNsec = √3 * UNsec * INsec . If the primary motoring energy is known, it must be converted to
secondary quantities using the following formula:
Setting
=
Psec
SN sec
=
PM
SNM
*
UNM
INM
*
UN prim
IN prim
The parameter .102 Dropout delay - the pickup holding time serves to extend pulsed pickups to the
parameterized minimum duration. A setting of 2 sec has proven to be suitable.
If reverse power without emergency tripping is used, a corresponding time delay must be implemented
to bridge any short reverse power states after synchronization or power swings subsequent to system
faults (e.g. 3-pole short circuit). Usually the .6 Operate delay (without Stop Valve) is set to approx. 10
sec.
Symbol
INM
Ratio CT
UNM
Ratio VT
Comments
Value
2854
Nominal machine current
A
A
1
15.00
kV
Nominal machine voltage
100
V Ratio of voltage transformer
4000
15000
V
A
Ratio of current transformer
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
26 / 70
B
INT
Reverse Power Protection (ANSI 32R)
Under emergency tripping conditions, the reverse power protection performs a short-time delayed trip
subsequent to the emergency tripping via an oil-pressure switch or a position switch at the emergency
trip valve. Before tripping, it must be ensured that the reverse power is only caused by the missing
drive power at the turbine side. A time delay is necessary to bridge the active power swing in case of
sudden valve closing. The parameter .103 Operate delay stop valve Time Delay Short (with Stop
Valve) is usually set to 1 sec.
General
Address
Parameter
Setting Options
.101
Rated current
primary
2853.65
A
Nominal machine current
.102
Rated voltage
primary
15.000
kV
Nominal machine voltage
.149
Power-sys.
neutral point
supressed coil grnd.
.158
P,Q sign
Presetting
Values
Comments
grounded
According power system neutral
point
grounded
grounded
not reversed
not reversed
Values
isolated
not reversed
reversed
In standard application the sign of
P and Q ist not reversed.
General
Address
Parameter
Setting Options
Presetting
.101
Angel correction
-10.00 … 10.00 °
0.00 °
.3
Minimum voltage
V1
percent
secondary
5.00 V
primary
Comments
0.00
°
10.00
%
5.77
V
0.866
kV
Nominal machine voltage
Threshold for minimum voltage.
Stage 1
Address
Parameter
.1
Mode
.2
Operate & flt.rec.
blocked
yes
.3
Threshold
percent
1)
Setting Options
on
off / test
no
Presetting
Values
Comments
on
on
Stage 1 must be activated
no
no
If yes - stage 1 has reporting effect
only.
- 1.00 %
-0.50
%
Threshold for reverse power 1)
.4
Dropout ratio
0.40 … 0.99
0.60
0.60
.102
Dropout delay
0.00 … 60.00 s
0.00 s
2.00
s
Pickup Holding Time
.6
Operate delay
0.00 … 60.00 s
10.00 s
10.00
s
To bridge power swings
.103
Operate delay stop
valve
0.00 … 60.00 s
1.00 s
1.00
s
Time Delay Short
Stage 1 drop out ratio
… the final pickup value has to be determined in primary tests during commissioning
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
27 / 70
B
INT
Turbine Overload Protection (ANSI 32T)
The turbine overload protection protects the STG shaft train components from inadmissible overload. It
is realized using a 2-stage forward power protection function connected with a CFC.
Stage P>
The first stage with a long time delay of 6 s uses a threshold that is 0.3% above rated active power. As
the threshold is set in MVA, the PF must be considered.
Stage P>
Address
Parameter
.1
Mode
.2
Operate & flt.rec.
blocked
.104
Meas. Value
.3
Threshold
Setting Options
on
off / test
yes
no
Presetting
Values
Comments
on
on
Stage must be activated
no
no
If yes - stage has reporting effect
only.
pos. seq. power
percent
- 1.00 %
85.3
%
Threshold related to apparent pow.
.101
Dropout ratio
0.40 … 0.99
0.60
0.95
.103
Tilt power char.
0.00 … 60.00 s
0.0 °
0.0
°
Tilt power char. for P> stage
.7
Dropout delay
0.00 … 60.00 s
0.00 s
0.00
s
P> stage dropout Time delay
.6
Operate delay
0.00 … 60.00 s
10.00 s
6.00
s
To bridge power swings
Stage drop out ratio
Stage P>>
The 2nd stage with a short time delay of 1 s uses a threshold that is 8% above rated active power. As
the threshold is set in MVA, the PF must be considered.
Stage 2 is blocked by a CFC logic for 6s when the plant is falling into island operation to avoid tripping
from power swings that may happen directly after Unit CB opening.
Stage P>>
Address
Parameter
Setting Options
.1
Mode
.2
Operate & flt.rec.
blocked
.104
Meas. Value
.3
Threshold
percent
.101
Dropout ratio
0.40 … 0.99
0.60
0.95
.103
Tilt power char.
0.00 … 60.00 s
0.0 °
.7
Dropout delay
0.00 … 60.00 s
.6
Operate delay
0.00 … 60.00 s
on
off / test
yes
no
Presetting
Values
Comments
on
on
Stage must be activated
no
no
If yes - stage has reporting effect
only.
pos. seq. power
91.8
%
Threshold related to apparent pow.
0.0
°
Tilt power char. for P>> stage
0.00 s
0.00
s
P>> stage dropout Time delay
10.00 s
1.00
s
To bridge power swings
Stage drop out ratio
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
Intern
28 / 70
B
INT
Underexcitation Protection (ANSI 40)
The underexcitation protection protects a synchronous machine from asynchronous operation in the
event of increasing grid voltage, faulty excitation or voltage regulation and prevents local overheating of
the rotor.
Functional Description
The following figure shows the loading diagram of the synchronous machine in the admittance plane
(P/U2; – Q/U2) with the static stability limit which crosses the reactive axis near 1/xd (reciprocal value
of the synchronous direct reactance).
The underexcitation protection in the 7UM85 makes available three independent, freely combinable
characteristics. As illustrated in the following figure, it is possible for example to model static machine
stability by means of two partial characteristics with the same time delays .6 Operate delay char. 1
and .8 Operate delay char. 2 . The partial characteristics are distinguished by the corresponding
distance from the zero point .3 1/xd characteristic 1 and .6 1/xd characteristic 2 as well as the
corresponding inclination .4 Angle characteristic 1 α1 and .7 Angle characteristic 2 α2.
If the resulting characteristic (1/xd char.1)/α1; (1/xd char.2)/α2 is exceeded (in the following figure on
the left), a delayed trip signal is transmitted. The delay is necessary to ensure that the underexcitation
limiter function within the voltage regulator is given enough time to increase the excitation voltage and
keep the generator in stable condition.
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
29 / 70
B
INT
Underexcitation Protection (ANSI 40)
A further characteristic (1/xd char.3) /α3 can be matched to the dynamic stability characteristic of the
synchronous machine. Since stable operation is impossible if this characteristic is exceeded, short time
tripping is then required by parameter .11 Operate delay char. 3 .
Settings
Symbol
UNM
15.00
Value
kV
Nominal machine voltage
INM
2854
A
Nominal machine current
xd
1.89
p.u.
Ratio VT
15000
V
Ratio CT
4000
A
63
Uexcit. 0
VDratio
20
Comments
Related machine synchronous direct reactance (unsaturated)
100
V Ratio of voltage transformer
1
A Ratio of current transformer
V
No-load excitation voltage
:
1
Ratio of voltage divider
xT
0.132
p.u.
Transformer reactance on generator MVA base
xGrid
0.030
p.u.
Grid reactance on generator MVA base
P1 / Q1
0.00
-0.49
p.u. from Generator capability diagram
P2 / Q2
0.44
-0.49
p.u. from Generator capability diagram
P3 / Q3
0.90
-0.44
p.u. from Generator capability diagram
The trip characteristics of the underexcitation protection in the admittance value diagram are
composed of straight segments which are respectively defined by their admittance 1/xd (=coordinate
distance) and their inclination angle α. The straight segments (1/xd char.1)/α1 (characteristic 1) and
(1/xd char.2)/α2 (characteristic 2) form the static underexcitation limit.
The underexcitation limiter in the AVR is set 10% before the char.1- char.2 underexcitation protection
curve, so that the AVR has enough time for raising the excitation.
The primary setting values for char.1 and char.2 can be read out directly from the diagram below. The
related secondary values must be converted for the protection setting by using the standard conversion
formula.
1
xd sec
=
1
I
U
* NM * N VT prim
IN CT prim
xd prim UNM
The setting values for char.3 are recommended as below:
1
xd CHAR3
≥ 1
Angle 3 = 80°…110°, typically 90°
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
30 / 70
B
INT
Underexcitation Protection (ANSI 40)
Excitation voltage query (only relevant for static excitation)
If static excitation is installed, the parameter .1 Mode V excitation< is set ON. In this case a short
delay .5 Operate delay is selected. The excitation voltage is connected via measuring transducer
TD3 and a voltage divider, so the protection can compare this voltage with the set value .4 Vexc< .
As soon as the excitation voltage falls below this value short-time tripping is initiated.
Vexc <
≈ 0.50 *
Uexcit. 0
63 V
= 0.50 *
= 1.5
VDRatio
20
V
Undervoltage Blocking
The admittance calculation requires a minimum measurement voltage. During a severe collapse (shortcircuit) or failure of stator voltages, the protection is blocked by an integrated AC voltage monitor
whose pickup threshold parameter .103 Threshold V1 min is set on delivery to 25 %. The parameter
value is based on phase-to-phase voltages.
V1 min =
0.25 * UNM * UN VT sec
UN VT prim
=
0.25 * 15.0 kV * 100 V
V
* √3
15000
= 14.4 V
General
Address
Parameter
Setting Options
Presetting
percent
.103
Threshold V1 min
secondary
15.00 V
primary
.10
Blk. by meas.-volt.
failure
yes
no
yes
Values
Comments
25.00
%
14.434
V
2.165
kV
yes
Ident-No.
Threshold for V1 min
If measuring-voltage failure
detected stage will be blocked
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
31 / 70
B
INT
Underexcitation Protection (ANSI 40)
0.00
0.10
0.20
0.30
0.40
0.50
0.60
0.70
0.80
0.90
1.00
0.00
P / SN
-0.10
-0.20
0,975
-0.30
0,95
-0.40
0,90
-0.50
-0.60
0,85
-0.70
0,20
0,40
0,60
0,80
0,70
-0.80
Permanent operation range (generator approximation)
practical SSSL (generator & xe)
Protection setting (Char.1 & Char.2)
Protection setting (Char.3)
Limiter setting
-0.90
-1.00
Q / SN
Characteristic
Address
Parameter
Setting Options
.1
Mode
.2
Operate & flt.rec.
blocked
yes
.3
1/xd char. 1
0.10 .. 5.00
0.70
-0.56
80
°
s
on
off / test
no
Presetting
Values
Comments
on
on
Stage must be activated
no
no
If yes - stage has reporting effect
only.
.4
Angle char. 1
50 .. 120°
70°
.5
Operate delay 1
0.00 .. 60.00 s
3.00 s
1,50
.6
1/xd char. 2
0.10 .. 5.00
0.45
-0.51
Suseptance Intersect Char. 1 1)
Inclination Angle of Char. 1
Characteristic 1 Time Delay
Suseptance Intersect Char. 2 1)
.7
Angle char. 2
50 .. 120°
110°
90
°
Inclination Angle of Char. 2
.8
Operate delay 2
0.00 .. 60.00 s
3.00 s
1,50
s
Characteristic 2 Time Delay
.9
1/xd char. 3
0.10 .. 5.00
1.40
-1.00
Suseptance Intersect Char. 3 1)
.10
Angle char. 3
50 .. 120°
90°
90
°
Inclination Angle of Char. 3
.11
Operate delay 3
0.00 .. 60.00 s
0.30 s
0.30
s
Characteristic 3 Time Delay
1)
… These settings are entered in Digsi as absolute values (without "-")
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
32 / 70
B
INT
Underexcitation Protection (ANSI 40)
V excitation <
Address
Parameter
.1
Mode
.2
Operate & flt.rec.
blocked
yes
.4
V exc<
-10.000 .. 10.000 V
1.500 V
.5
Operate delay
0.00 .. 60.00 s
0.50 s
.101
Sensor
Setting Options
on
off / test
no
Transducer. Uexc
Transducer(2Hz)/ etc.
Presetting
Values
Comments
on
off
Stage must be activated for static
excitation only
no
no
If yes - stage has reporting effect
only.
1.50
0.50
V
s
Operate delay for V exc< crit.
Transducer. Uexc (ph-ph)
Ident-No.
Threshold for V exc< criterion
Additional Sensor can be
implemented
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
33 / 70
B
INT
Unbalanced Load Protection (ANSI 46)
The unbalanced load protection detects asymmetrical loads of three-phase induction machines.
Unbalanced loads create a counter-rotating field which acts on the rotor at double frequency. Eddy
currents are induced on the rotor surface, leading to local overheating at the transition between the slot
wedges and the winding bundles. Another effect of unbalanced loads is overheating of the damper
winding. It is also useful for detecting 1-pole and 2-pole faults with magnitudes lower than the load
currents.
Functional Description
Thermal Characteristic
If the negative-sequence current I2 continuously exceeds the parameter .101 Max. continuously
perm. I2 a warning message is issued after expiry of a set time .104 Warning delay .
Limitation
To avoid overfunctioning of the thermal tripping stage during asymmetrical short circuits, the input
current I2 is restricted. This limit is 10 * perm I2. Above this current value the tripping time of the
thermal function is constant. In addition the thermal memory is limited to 200% of .102 Unbalanced
load factor K . This avoids prolonged cooling after a delayed short circuit tripping.
Cool Down
A cool-down time with adjustable parmeters starts as soon as the constantly permissible unbalanced
load .101 Max. continuously perm. I2 is undershot. The tripping drops out on dropout of the pickup.
However, the counter content is reset to zero with the cooling time parameterized at address .103
Cooling time therm. replica .
Tripping Stages
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
34 / 70
B
INT
Unbalanced Load Protection (ANSI 46)
Settings
Symbol
Kprim
10
I2 max prim
10.00
INM
Ratio CT
Value
s
Asymmetry factor (machine constant, primary side)
% INM
relative permissible long-term thermal inverse machine current (primary)
A
2854
4000
Comments
A
Nominal machine current
1
A Ratio of current transformer
It is important to note that the manufacturer's data relate to the primary values of the machine, for
example, the maximum permissible permanent inverse current referring to the nominal machine
current is indicated. The following applies:
Pickup Threshold / Warning Stage
I
perm I2 =
I2 max prim
+
1 %
=
10
%
+
1 %
=
11.0
%
The factor K can be derived from the unbalanced load characteristic according to the figure below by
reading the time corresponding to the FACTOR K at the point I2/IN = 1. The constant Kprimary
determined in this way is valid for the machine side (primary side).
Kprim
The parameter .103 Cooling time therm. replica establishes the time required by the protection
object to cool down under admissible unbalanced load I2> to the initial value. The setting value can be
calculated by assuming an equal value for cooldown time and heatup time of the object to be
protected. The machine manufacturer indicates the permissible unbalanced load by means of the
following formula for the thermal characteristic:
Cooling time therm.
replica
=
tCooldown
=
Kprim
I2 max prim
(
)²
INM
=
(
10
0.10
Ident-No.
s
)²
≈
1000
0-76620-BB2284A-30
s
Sheet
Blatt
Revision
Classification
35 / 70
B
INT
Unbalanced Load Protection (ANSI 46)
Address
Parameter
.1
Mode
.2
Operate & flt.rec.
blocked
Setting Options
on
off / test
yes
no
Presetting
Values
Comments
on
on
Thermal stage must be active.
no
no
If yes - Thermal stage has
reporting effect only.
.101
max. Cont perm I2
percent
10.0 %
11.0
%
Threshold for Continously I2perm
.102
Unbal. load factor k
1.0 … 100.0 s
15.0 s
10.0
s
Unbalanced load factor k
.103
Cool. time th. replica
0 … 50000 s
1500 s
1000
s
Cooling time therm. replica
.104
Warming delay
0.00 … 60.00; ∞ s
15.0 s
4.0
s
Time delay for warning stage
Definite-Time Tripping Characteristic
High negative phase sequence currents can only be caused by a two-pole power system short circuit
which must be covered in accordance with the network grading plan. For this reason, the thermal
characteristic is cut by a selectable, independent negative phase-sequence current stage of 10 x .101
Max. continuously perm. I2 .
The heating up of the object to be protected is calculated in the device as soon as the permissible
unbalanced load I2> is exceeded. In this context, the current-time-area is calculated constantly to
ensure a correct consideration of various load cases. As soon as the current-time-area ((I2/IN)² * t) has
reached the K asymmetry factor, the thermal characteristic is tripping.
Asymmetrical faults also cause high negative phase-sequence currents. A definite-time negative phasesequence current stage characteristic .3 Threshold (Definite-Time) can thus detect asymmetrical
power system short circuits. A setting at 30 % ensures that tripping always occurs in accordance with
the thermal characteristic except in case of a single phase failure (I2 ~ 0,33 IN) or worse. The .6
Operate delay must be set slightly higher then I> protection delay time.
General
Address
Parameter
Setting Options
.106
Reference value
.107
Current limitation
Imax
yes
5.0
%
.104
Release current
secondary
0.036
A
primary
143
A
rated current
pos. seq. Current
no
percent
Presetting
Values
Comments
rated current
rated current
Reference value to be selected
no
no
Current limitation must be set to no
5.0 %
Threshold for release current
Definite-Time
Address
Parameter
Setting Options
.1
Mode
.2
Operate & flt.rec.
blocked
yes
.3
Threshold
percent
on
off / test
no
Presetting
Values
Comments
on
on
Definite-Time stage must be active.
no
no
If yes - Definite-Timel stage has
reporting effect only.
10.0 %
30.0
%
Threshold for Definite-Time
.4
Dropout ratio
0.40 … 0.99
0.95
0.95
.101
Dropout delay
0.00 … 60.00 s
0.00 s
0.00
s
Definite-Time Dropout delay
.6
Operate delay
0.00 … 60.00 s
4.00 s
4.00
s
Definite-Time Operate delay
Definite-Time Dropout ratio
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
36 / 70
B
INT
Thermal Over Load Protection (ANSI 49)
The device is measuring the stator current and calculates the overtemperature in accordance with a
single-body thermal model, based on the following differential equation.
Functional Description
The protection function models a thermal profile of the equipment being protected (overload protection
with memory capability). Both the previous history of an overload and the heat loss to the environment
are taken into account. Current influence of single body thermal model will be set to limitation via .114
Behav. at I>Imax therm. parameter.
The overtemperature is calculated from the largest of the three phase currents. Since the calculation is
based on RMS values of currents, harmonics which contribute to a temperature rise of the stator
winding are also considered. The ambient temperature is not measured according parameter .44
Temperature sensor (= none) and set to 40°C with parameter .118 Default temperature . The .117
Minimal temperature limits the coupled ambient temperature.
Settings
Symbol
Imax prim
2996
A
INM
2854
A
Ratio CT
Tth
Value
4000
418
A
Comments
1
s
Thermally continuous permissable current
Nominal machine current
A Ratio of current transformer
Thermal time constant
The maximum thermally permissible continuous current Imax is described as a multiple of the nominal
current IN of the protected object:
Imax
=
k * IN
The overload protection is set with quantities per unit. The nominal current INM of the object to be
protected (generator) is typically used as base current for overload detection. The thermally permissible
continuous current Imax prim can be used to calculate a the parameter .106 K-factor :
K-factor
=
Imax prim
INM
=
2996
2854
A
A
=
1.05
The overload protection tracks overtemperature progression, employing a thermal differential equation
whose steady state solution is an exponential function. The .110 Thermal time constant is used in the
calculation to determine the threshold of excess temperature and thus the tripping temperature.
If the overload characteristic of the generator to be protected is pre-determined, the user must select
the protection trip characteristic so that it largely corresponds to the overload characteristic, at least for
small overloads. This is also the case if the admissible power-up time corresponding to a certain
overload value is indicated.
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
37 / 70
B
INT
Thermal Over Load Protection (ANSI 49)
By setting the thermal warning level .104 Threshold thermal warn. , a warning message can be
issued before the tripping temperature is reached, thus avoiding tripping by promptly reducing load.
The thermal alarm level is given in % of the tripping overtemperature level.
Θ
ΘTrip
=
100%
=
(K-factor)²
100 %
= 90.7 %
1.05 ²
< ΘTrip
= 91 %
< .104 Thres.
=
100 %
Parameter .101 Threshold current warning results in the same setting as the K-factor in percent and
secondary setting must be calculated as follows:
Threshold Ther. Warn
Threshold Ther. Warn
=
Imax prim
INM
≤ K-factor
*
INM
IN CT prim
=
* IN CT sec
2996
2854
≤
A
2854
*
A
4000
0.75
*
1
A
A
=
0.75
A
A
=
0.75
A
The parameter .107 Imax thermal specifies up to which current value the trip times are calculated in
accordance with the prescribed formula. In the trip characteristics, this limit value determines the
transition to the horizontal part of the characteristics, where there is no further trip time reduction
despite increasing current values. The selected limit value ensures that even for the highest possible
short-circuit current, the trip times of the overload protection definitely exceed the trip times of the shortcircuit protection devices (impedance protection, time overcurrent protection). As a rule, a limitation to
a secondary current corresponding to roughly three times the nominal machine current will be
sufficient.
Imax thermal
= 3.00 * INM *
IN CT sec
IN CT prim
= 3.00 * 2854
A *
1
4000
A
A
=
2.14
A
The run-on time to be entered at address .112 Emerg. start Tovertravel must be sufficient to ensure
that after an emergency startup and dropout of binary input „>Emer.Start O/L“ the trip command is
blocked until the thermal replica is again below the dropout threshold.
On slowing down or standstill, the machine cool down slowly. This behaviour can be modeled by the
time constant .111 Cooling time constant .
The automatic switchover to the .111 Cooling time constant can be set via .108 Imin cooling
parameter. A default setting of Iminsec. = 0.5A will be used. The maximal allowed temperature rise
above the set ambient temperature (.118 Default temperature ) can be set with .109 Temperature
rise at Irated . A default setting of 70K will be recommended.
The .105 Dropout threshold operate parameter is used to drop out pickup and tripping when the
value drops below this threshold.
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
38 / 70
B
INT
Thermal Over Load Protection (ANSI 49)
Address
Parameter
.1
Mode
.2
Operate & flt.rec.
blocked
.101
Threshold thermal
warn.
Setting Options
on
off / test
yes
no
Presetting
Values
Comments
on
on
Stage must be active.
no
no
If yes - stage has reporting effect
only.
percent
secondary
105.0
5
primary
%
0.75
A
2996
A
Threshold for thermal warning
.104
Thr. thermal warn.
percent
10.0 %
90.0
%
Threshold for thermal warning
.105
Dropout thr. operate
percent
10.0 %
90.0
%
Dropout threshold for operate
.112
Emerg.start Tover
0…15000 s
300 s
300
s
Emergency start T-overtravel
s
Thermal time constant
3600
s
Cooling time constant
300.0
%
.106
K-factor
0.10 … 4.00
1.10
1.05
.110
Thr. time constant
10 … 60000 s
900 s
418
.111
Cooling time const.
10 … 60000 s
3600 s
percent
.107
.108
Imax thermal
Imin cooling
secondary
2.140
A
primary
8561
A
percent
70.1
%
0.500
A
2000.00
A
70
K
secondary
2.5 A
K-factor
0.5 A
primary
Below this value there is an
automatic switchover to the cooling
time constant
T rise at Irated
40 … 200 K
.113
Storage of
thermal replica
yes
.114
Behav. at I> Imax
therm.
.144
Temperature
sensor
none
.118
Default temperature
-55°C … 55°C
40 °C
40.0
°C
Default ambient temperature
.117
Minimal temperature
-55°C … 40°C
-20°C
-20.0
°C
Only relevant with temp. sensor
.109
no
current limiting
freeze therm. rep.
…
70 K
Theshold for Imax thermal current
yes
yes
Storage of thermal replica must be
selected
current
limiting
current limiting
Current limiting behaviour must be
selected.
none
none
Temeprature sensor is not
implemented.
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
39 / 70
B
INT
Definite Time Overcurrent Protection (I>>, ANSI 50)
The time-overcurrent protection is used as backup protection for the differential protection of the
protected object. It also provides backup protection for downstream network components if faults there
are not disconnected in time thus endangering the protected object.
In order to ensure that pick-up always occurs even with internal faults, the protection - for generators is usually connected to the current transformer set in the neutral leads of the machine.
Functional Description
Each phase-current of side 2 is compared individually with the common pickup value .3 Threshold ,
and indicated on overshoot. A trip signal is transmitted to the matrix as soon as the corresponding time
delay .6 operate delay has expired.
Due to the higher pick-up setting this function is mainly important and in charge for internal faults within
the generator area as a short time trip. External faults upstreams of transformer would be covered by
the I> protection.
Settings
Symbol
Value
INM
2854
Ratio CT
4000
A
Comments
A
Nominal machine current
1
A
Ratio of current transformer
A value of four times the nominal generator current has proven to be sufficient setting for Threshold
I>>. The settings regarding pick-up current and time delay are usually accepted pre-settings for
delivery. These settings have to be coordinated or adapted according the selectivity calculation of the
plant.
Threshold I>>
= 4.00 *
INM
2854
* IN CT sec = 4.00 *
4000
IN CT prim
Address
Parameter
Setting Options
.1
Mode
.2
Operate & flt.rec.
blocked
yes
.8
Method of
measurement
fundamental
on
off / test
no
RMS
Threshold
secondary
Operate delay
0.00 … 100.00 s
=
2.85
A
Values
Comments
on
on
Stage I>> must be activated
no
no
If yes - stage I>> has reporting
effect only.
fundamental
fundamental
Harmonics or transient voltage
peaks will be suppressed
1.5 / 7.5 A
primary
.6
A
Presetting
percent
.3
A
* 1
A
0.30 s
400.00
%
2.854
A
11415
A
0.50
s
Ident-No.
Threshold for I>> overcurrent
I>> Time Delay
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
40 / 70
B
INT
Inadvertent Energization (ANSI 50/27)
The inadvertent energization protection has the task to limit damage caused by the accidental
energization of the stationary or already started, but not yet synchronized generator by fast opening the
generator circuit breaker. A grid connection to a stationary machine is equivalent to connecting to a lowohmic resistor. Due to the nominal voltage impressed by the power system, the generator starts up
with a high slip as an asynchronous machine. Thereby inadmissibly high currents are induced in the
rotor which could destroy it.
Settings
Symbol
UNM
Value
Comments
15.00
kV
Nominal machine voltage
INM
2854
A
Nominal machine current
Ratio VT
15000
V
100
V Ratio of voltage transformer
Ratio CT
4000
A
1
A Ratio of current transformer
The inadvertent energizing protection may only be effective if the device is either in operational
condition 0 or if no nominal conditions have been reached yet. Parameter .3 Threshold serves to
specify the current pickup threshold of the inadvertent energization protection function. As a rule, this
threshold value is set more sensitively than the threshold value of the time-over-current protection. The
typical setting is 30% In. The parameter .101 V< Threshold serves to define these nominal conditions.
The typical setting is about 50 % of the nominal voltage.
The parameter .103 Pickup delay represents the time delay for the release of the tripping condition
with undervoltage. The setting remains at the presetting of 5 sec, it must always be higher then the
time delay of the overcurrent protection I>.
The delay time to block the tripping conditions when the voltage is above the undervoltage threshold is
set at .7 Dropout delay . The inadvertent energizing protection is blocked only after this time in order
to enable a tripping subsequent to connection.
I Threshold
=
V< Threshold =
0.30 * 2854 A *
30 % * INM * IN CT sec
=
4000
IN CT prim
0.50 * UNM * UN VT sec
UN VT prim
Address
Parameter
Setting Options
.1
Mode
.2
Operate & flt.rec.
blocked
yes
.10
Blk. by meas.-volt.
failure
yes
.3
Threshold
secondary
on
off / test
no
no
percent
=
=
0.21
A
0.50 * 15.00 kV * 100 V
= 50.0 V
15.00
kV
Presetting
Values
Comments
on
on
Stage 1 must be activated
no
no
If yes - stage 1 has reporting effect
only.
yes
yes
If measuring-voltage failure
detected U< stage will be blocked
30 %
primary
percent
A
A
1
50 %
30.0
%
0.214
A
856
A
50.000
%
50.000
V
Threshold for I criterion
.101
V< Threshold
secondary
7.50
kV
.103
Pickup delay
0.00 … 60.00 s
5.00 s
5.00
s
Pickup Time Delay V<
.7
Dropout delay
0.00 … 60.00 s
1.00 s
1.00
s
Dropout time delay V<
primary
Ident-No.
Threshold for V< criterion
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
41 / 70
B
INT
Breaker Failure Protection (ANSI 50BF)
The breaker failure protection monitors whether the associated circuit breaker is opened correctly. In
generator protection it concerns usually the generator circuit breaker.
Functional Description
If the circuit breaker has not opened after a programmable time delay (breaker failure), a higher-level
circuit breaker must initiate disconnection (see the following example).
Settings
Symbol
UNM
Value
15.00
kV
INM
2854
A
Ratio VT
15000
V
Ratio CT
4000
A
Ik3~
4300
Comments
Nominal machine voltage
Nominal machine current
100
V Ratio of voltage transformer
1
A Ratio of current transformer
A
Generator short circuit Ik3~ sustained
The parameter .107 Start via binary input may be used to start the breaker failure function from an
external source (e.g. a further protection relay). As default value this is not used and therefore set to
no.
The parameter .104 Dropout shows the dropout criteria for the breaker failure function, where as
default the CB auxiliary contact and the current criteria are used.
The parameters .102 Threshold phase current , .101 Threshold sensitive , .122 Threshold 3Io dir.
release and .123 Threshold I2 dir. release will set to 50% of nominal machine current.
Threshold
≈
50 % * INM * IN CT sec
0.50 * 2854 A *
=
4000
IN CT prim
Ident-No.
1
A
A
=
0.36
0-76620-BB2284A-30
A
Sheet
Blatt
Revision
Classification
42 / 70
B
INT
Breaker Failure Protection (ANSI 50BF)
Address
Parameter
Setting Options
.1
Mode
.105
Holding int. start
signal
yes
.107
Start via binary
input
no
.103
CB aux.cont. crit.
allowed
.104
Dropout
.108
Retrip after T1
.102
Threshold phase
current
on
off / test
no
1channel/ 2 channel
no
w.CB pos. closed 3p.
with effective crit.
w.aux.c. and curr. crit.
no
parallel T2,T1/ T2 after T1
Presetting
Values
Comments
on
on
ANSI50BF must be activated
yes
yes
It is recommended to use this
methode (yes)
no
no
"No" if no external start is intended
no
w.CB pos. closed 3p.
Aux contacts must be permitted as
a further criterion.
with effective
crit.
w.aux.c. and curr. crit.
If current is not reliable criterion for
detecting opening of CB
no
parallel start T2, T1
Parallel start of T1 and T2 will be
used
percent
50.0
%
secondary
0.357
A
primary
1427
A
percent
50.0
%
0.357
A
1427
A
0.00
s
Delay T1 for 3-pole retrip
.101
Threshold
sensitive
secondary
.109
Delay T1 for retrip
0.00 … 60.00 s
primary
0.05 s
Threshold for I phase criterion
Threshold for I sensitive criterion
.110
Delay T2 for trip
0.00 … 60.00 s
0.13 s
0.25
s
Delay T2 for 3-pole trip
.112
Minimum oper. time
0.00 … 60.00 s
0.10 s
1.00
s
Minimum operate time
.120
3 I0 criterion
Direct release
Plausibility
check
Plausibility check
The ground current is only used to
check the phase currents
.108
I2 criterion
Plausibility
check
Plausibility check
The negative-sequence current is
only used to check plausibility
percent
50.0
%
.122
Threshold 3 I0 dir.
release
secondary
0.357
A
primary
1427
A
Threshold I2 dir.
release
percent
50.0
%
secondary
0.357
A
primary
1427
A
.154
Immediate dropout
activated / deactivated
activated
CB BF drops out immediately
.155
BI start ext. latch
activated / deactivated
activated
BI supervision remains inactive
.123
Plausibility check
Direct release
Plausibility check
Ident-No.
This parameter is only affective if 3
I0 critierion = direct release
This parameter is only affective if I2
critierion = direct release
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
43 / 70
B
INT
Sensitive Earth Fault Protection (ANSI 51GN)
The sensitive earth current protection detects earth faults in systems with earthed starpoint. This stage
operates with the magnitudes of the earth current only. It is therefore useful in applications where the
magnitude of the earth current is an indicator of the earth fault. This may be the case e.g. in electrical
machines in a busbar configuration. The current can be measured using torroidal current transformers
or Holmgreen connection.
Functional Description
The sensitive earth current protection can be used as a backup protection to detect earth faults in the
stator, provided that the magnitude of the earth current alone is sufficient as a trip criterion.
Settings
Symbol
UNM
Value
15.00
UN NT prim
UN NT sec
15.00
/ √3
RLoad
200
kV
Nominal machine voltage
kV
Nominal earthing transformer voltage (primary) (if applicable)
V
500
Ratio CT
Comments
A
5.00
Nominal earthing transformer voltage (secondary) (if applicable)
5
Ω
A Ratio of CTprim / CTsec on secondary side of earthing transformer (if applicable)
Resistance of the load resistor (if applicable)
General
Comments
Address
Parameter
Setting Options
Presetting
Values
.103
Dropout delay
0.00 … 60.00s
1.00 s
.104
Core balance CT1
0.10 … 160.00 %
5.00 %
5.00
%
Core balance CT-current 1
.105
Core balance CT2
0.10 … 160.00 %
100.00 %
100.00
%
Core balance CT-current 2
.106
CT angle error I1
0.0 … 5.0 °
0.0 °
0.0
°
CT angle error at I1
.107
CT angle error I2
0.0 … 5.0 °
0.0 °
0.0
°
CT angle error at I2
1.00
s
Ident-No.
To avoid chattering
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
44 / 70
B
INT
Sensitive Earth Fault Protection (ANSI 51GN)
For the use as Stator Earth Fault Detection in busbar connection, the same settings as for the 90%
SEF Protection 3I0> are used.
For the use as Stator Earth Fault Detection in unit connection, the settings reflect 10% current through
NGT (90% protection range).
UN NT sec
* 10%
RLoad
3I0>
=
3I0>%
=
10.00
200
3I0> sec
=
3I0>
=
/
500 V
* 0.10
5.00 Ω
=
0.05
CTprim
CTsec
=
=
10.00
5
A /
=
10.00
=
250.0 mA
Calculation for unit
connection
A
%
200
5
3I0>1
Address
Parameter
Setting Options
.1
Mode
.2
Operate & flt.rec.
blocked
yes
.8
Method of
measurement
fundamental
on
off / test
no
RMS
percent
.3
Threshold
Presetting
Values
Comments
on
on
Stage 3I0> 1 must be activated
no
no
If yes - stage 3I0> 1 has reporting
effect only.
fundamental
fundamental
Harmonics or transient voltage
peaks will be suppressed
5.000 %
5.000
%
secondary
0.25
A
primary
10
A
Threshold for 3I0> 1 criterion
.102
Pickup delay
0.00 … 60.00s
0.00 s
0.00
s
3I0 > Stage Pickup delay time
.6
Operate delay
0.00 … 100.00s
0.30 s
0.30
s
3I0 > Operate Time delay
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
45 / 70
B
INT
Definite Time Overcurrent Protection (I>, ANSI 51V) with
Undervoltage Seal-In
The time-overcurrent protection is used as backup protection for the differential protection at internal
faults and the upstream OC protection devices at external faults of the protected object. It also
provides backup protection for downstream network components if faults there are not disconnected in
time thus endangering the protected object.
Functional Description
Each phase current of side 2 is compared individually with the common setting value .3 Threshold
and on overshoot signaled individually. A trip signal is transmitted to the matrix as soon as the
corresponding time delay .6 Operate delay has expired.
Settings
Symbol
UNM
Value
Comments
15.00
kV
Nominal machine voltage
INM
2854
A
Nominal machine current
Ratio VT
15000
V
100
V Ratio of voltage transformer
Ratio CT
4000
A
1
A Ratio of current transformer
ΔUNM-
5
%
Negative nominal machine voltage tolerance
The settings regarding pick-up current and time delay are usually accepted pre-settings for delivery.
These settings have to be coordinated or adapted according the selectivity calculation of the plant.
The setting calculation of .3 Threshold is based on 120% of maximum permissible current at
minimum continuous permissible voltage tolerance of generator.
Threshold i>
= 1.20 *
Threshold i>
=
i>
105
100
= 1.26
1.26 * 2854 A *
* INM * IN CT sec
=
4000
IN CT prim
1
A
A
= 0.90 A
0.7 * 15.0 kV * 100 V
15000
√3
V
= 40.4 V
The setting of U< is based on 70% of nominal generator voltage.
V-seal in
Threshold
=
0.7 * UNM * UN VT sec
UN VT prim
=
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
46 / 70
B
INT
Definite Time Overcurrent Protection (I>, ANSI 51V) with
Undervoltage Seal-In
Address
Parameter
.1
Mode
.2
Operate & flt.rec.
blocked
yes
percent
126.0
%
.3
Threshold
secondary
0.899
A
primary
3596
A
3.00
s
1)
Setting Options
on
off / test
no
Presetting
Values
Comments
on
on
Stage 1 must be activated
no
no
If yes - stage 1 has reporting effect
only.
.6
Operate delay
0.00 … 60.00 s
.10
Blk. by meas.-volt.
failure
yes
.101
State of V-seal-in
V-seal-in
Threshold
percent
70.00
%
.102
secondary
40.415
V
6.062
kV
.104
V-seal-in time
0.00 … 60.00 s
4.00
s
no
on
off
3.00 s
Threshold for Definite time
overcurrent with Undervoltage Sealin
T I> Time Delay
1)
yes
yes
If measuring-voltage failure
detected U< stage will be blocked
on
on
Undervoltage seal in must be
activated
primary
4.00 s
Undervoltage Seal-In Pickup
Threshold
Duration of V< Seal-In (> "T I>")
… depends on network time grading plan
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
47 / 70
B
INT
Inverse-Time Overcurrent Protection (ANSI 51V)
The inverse-time overcurrent protection is used as back-up protection for the machine short-circuit
protection (differential protection and/or impedance protection). It provides back-up protection for
network faults that can not be cleared immediately and thus endanger the machine.
Settings
Symbol
UNM
Value
15.00
INM
Comments
kV
2854
A
Nominal machine voltage
Nominal machine current
Ratio VT
15000
V
100
V Ratio of voltage transformer
Ratio CT
4000
A
1
A Ratio of current transformer
It must be considered that, for the inverse O/C time protection, a safety factor of about 1.1 has already
been included between the pick-up value and the setting value. This means that a pickup is only
performed if a current of about 1.1 times the setting value is present. The function will reset as soon as
the value falls below 95 % of the pickup value (0.95 * 1.1 = 1.045).
The current value is set at address .3 Threshold . The maximum operating current is of primary
importance for the setting. A pickup caused by an overload must be excluded, as the device operates
in this mode as fault protection with correspondingly short tripping times and not as overload protection.
Threshold Ip
=
1.1 * INM * IN CT sec
=
IN CT prim
1.1 * 2854 A *
4000
1
A
A
= 0.78 A
Setting: 20% - 30% over the expected peak load
With the .130 Type of character. curve parameter 7 ANSI curves and 4 IEC curves can be selected.
The pickup current is set at address .3 Threshold , the corresponding time multiplier for configuration
of IEC as well as ANSI characteristics is accessible at address .103 Time dial .
With parameter .104 Undervoltage threshold serves to predefine the U< pick-up value for the
undervoltage release of the Ip pickup value for voltage-controlled inverse overcurrent time protection.
The parameter is set to a value just below the lowest phase-to-phase voltage admissible during
operation, preferably 75 %.
Undervoltage
Threshold
=
0.75 * UNM * UN VT sec
UN VT prim
=
0.75 * 15.0 kV * 100 V
=
15
kV
75
V
The .102 Reset parameter allows you to define whether the stage decreases acording to the dropout
characteristic curve, behavior of a disk emulation = rotor disc or instantaneously. The usage of disk
emulation is recommended.
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
48 / 70
B
INT
Inverse-Time Overcurrent Protection (ANSI 51V)
The inverse overcurrent time protection is provided with a undervoltage detection that can be disabled.
This function can influence overcurrent detection in two different ways:
- Voltage controlled:If the value falls below a settable voltage threshold, an overcurrent stage is
enabled.
- Voltage restraint:The pickup threshold of the overcurrent stage depends on the voltage level. A lower
voltage reduces the current pickup value. A linear, directly proportional dependency is realized in the
zone between U/UNom = 1.00 to 0.25. Consequently, the following rule applies:
Address
Parameter
.1
Mode
.2
Operate & flt.rec.
blocked
yes
.10
Blk. by meas.-volt.
failure
yes
.8
Method of
measurement
fundamental
.3
Threshold
.101
Type of character.
curve
.102
Reset
103
.104
Setting Options
on
off / test
no
no
RMS
Presetting
Values
Comments
on
on
Stage 1 must be activated
no
no
If yes - stage 1 has reporting effect
only.
yes
yes
If measuring-voltage failure
detected U< stage will be blocked
fundamental
fundamental
Harmonics or transient voltage
peaks will be suppressed
percent
110.00
%
secondary
0.785
A
primary
3139
A
ANSI
IEC
disk emulation
Threshold for inverse time
overcurrent
ANSI long-time inv.
7 ANSI and 4 IEC curves can be
selected
disk emulation
Disk emulation for reset parameter
recommended
instantaneous
disk
emulation
Time dial
0.05 … 15.00 s
1.00 s
Undervoltage
Threshold
percent
75.00 %
secondary
primary
11250
V
1.00
s
75.00
%
75.000
V
Ident-No.
TIME DIAL: TD
Undervoltage Seal-In Pickup
Threshold
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
49 / 70
B
INT
Overvoltage Protection (ANSI 59)
Overvoltage protection serves to protect the electrical machine and connected electrical plant
components from the effects of inadmissible voltage increases. Overvoltages can be caused by
incorrect manual operation of the excitation system, faulty operation of the automatic voltage regulator,
(full) load shedding of a generator, separation of the generator from the system or during island
operation.
Functional Description
The overvoltage protection for medium voltage generators is monitoring the phase-to-phase voltages.
In case of a high overvoltage, trip is performed with a short-time delay, whereas in case of less severe
overvoltages, the trip is performed with a longer time delay. Voltage thresholds and time delays are set
individually for both elements.
Settings
Symbol
UNM
Ratio VT
Value
15.00
15000
ΔUNM+
V
5
Comments
kV
Nominal machine voltage
100
V Ratio of voltage transformer
%
Positive nominal machine voltage tolerance
The setting of limit values and time delays of the overvoltage protection depends on the speed with
which the voltage regulator can control voltage variations. The protection must not intervene in the
regulation process of the faultlessly functioning voltage regulator. For this reason, the two-stage
characteristic is set always above the voltage time characteristic of the regulation procedure.
The long-time stage U> will be activated with .1 Mode and must intervene in case of steady-state
overvoltages. Depending on the generator voltage tolerance it is set to a value between 115 % to 120
% UN at parameter .3 Threshold (U>) with a time delay of 3s at .6 Operate delay parameter.
Threshold U>
=
1.15 * UNM * UN VT sec
UN VT prim
=
1.15 * 15.00 kV * 100 V
=
15
kV
115.0
V
In case of a full-load rejection of the generator, the voltage increases first in relation to the transient
voltage. Only then the voltage regulator reduces it again to its nominal value. The U>> stage is set
generally as a short-time stage in a way that the transient procedure for a full-load rejection does not
lead to a tripping. For example parameter .3 Threshold (U>>) about will be set 130 % to 135 % UN
with a delay of 0.75s according .6 Operate delay parameter.
U>> =
1.30 * UNM * UN VT sec
UN VT prim
=
1.30 * 15.00 kV * 100 V
15
V
=
130.0
V
The dropout ratio for U> and U>> stage can be adapted at the address .4 Dropout ratio in small
stages to the operating conditions and used for highly precise signalizations.
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
50 / 70
B
INT
Overvoltage Protection (ANSI 59)
Definite-T (U>)
Address
Parameter
.1
Mode
.2
Operate & flt.rec.
blocked
.9
Measured value
.8
Method of
measurement
.101
Pickup mode
Setting Options
on
off / test
yes
no
ph-gnd
ph-ph
fundamental
RMS
1oo(3)
3oo(3)
percent
.3
Threshold
Presetting
Values
Comments
on
on
Stage U> must be activated
no
no
If yes - stage U> has reporting
effect only.
ph-ph
ph-ph
Phase - Phase voltage will be
measured
fundamental
fundamental
Harmonics or transient voltage
peaks will be suppressed
1oo(3)
1oo(3)
U> pickup if 1 out of 3 voltages are
below Threshold.
110.00 %
115.000
%
secondary
115.000
V
primary
17.250
kV
U> overvoltage threshold
.4
Dropout ratio
0.90 … 0.99
0.95
0.95
.6
Operate delay
0.00 … 300.00 s
3.00 s
3.00
Setting Options
Presetting
Values
Comments
on
on
Stage U>> must be activated
no
no
If yes - stage U>> has reporting
effect only.
ph-ph
ph-ph
Phase - Phase voltage will be
measured
fundamental
fundamental
Harmonics or transient voltage
peaks will be suppressed
1oo(3)
1oo(3)
U>> pickup if 1 out of 3 voltages
are below Threshold.
U > Stage drop out ratio
s
U > Operate Time delay
Definite-T (U>>)
Address
Parameter
.1
Mode
.2
Operate & flt.rec.
blocked
.9
Measured value
.8
Method of
measurement
.101
Pickup mode
on
off / test
yes
no
ph-gnd
ph-ph
fundamental
RMS
1oo(3)
3oo(3)
percent
.3
Threshold
130.00 %
130.000
%
secondary
130.000
V
primary
19.500
kV
.4
Dropout ratio
0.90 … 0.99
0.95
0.95
.6
Operate delay
0.00 … 300.00 s
0.50 s
0.75
U>> overvoltage threshold
U >> Stage drop out ratio
s
Ident-No.
U >> Operate Time delay
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
51 / 70
B
INT
90% Stator Earth Fault Protection (ANSI 59N)
The stator earth fault protection detects earth faults in the stator windings of three-phase machines.
The machine is operating in unit connection (via unit transformer). The criterion for the occurrence of
an earth fault is mainly the emergence of a displacement voltage. This principle allows a protected
zone of 90 % up to 95 % of the stator winding.
Functional Description
The displacement voltage UE can be measured either via the e-n winding (broken delta winding) of a
voltage transformer set or at the machine starpoint via voltage transformers or neutral earthing
transformers or the measurement winding of a line connected earthing transformer or the device can
calculate the displacement voltage from the phase-to-earth voltages (standard). For safety reasons the
calculated displacement voltage is used by default.
Settings
Symbol
UNM
Ratio VT
Value
15.00
15000
V
Comments
kV
Nominal machine voltage
100
V Ratio of voltage transformer
A setting of 10% of the full displacement voltage is chosen to avoid pick up on normal operational
asymmetries.
U0> =
0.10 * UNM * UN VTsec
UN VT prim
* √3
0.10
=
* 15.00 kV * 100 V
=
* √3 kV
15.00
5.8
V
General
Address
Parameter
Setting Options
Presetting
Values
.103
Dropout delay
0.00 … 60.00 s
1.00 s
Address
Parameter
Setting Options
Presetting
Values
Comments
.1
Mode
on
on
Stage V0> must be activated
.2
Operate & flt.rec.
blocked
yes
no
no
If yes - stage V0> has reporting
effect only.
.10
Blk. by meas.-volt.
failure
yes
yes
yes
If measuring-voltage failure
detected V0> stage will be blocked
.109
Detection of faulty
phase
yes
yes
no
.8
Method of
measurement
fundamental comp.
fundamental
fundamental comp.
.3
Threshold
secondary
5.781
V
primary
0.866
kV
1.00
Comments
s
To avoid chattering
V0>
on
off / test
no
no
no
RMS
percent
10 %
10.00
Harmonics or transient voltage
peaks will be suppressed
%
V0> voltage threshold
.4
Dropout ratio
0.90 … 0.99
0.95
0.95
.107
Pickup delay
0.00 … 300.00 s
0.00 s
0.00
s
V0> Pickup time delay
.6
Operate delay
0.00 … 300.00 s
0.30 s
0.30
s
V0 > Operate Time delay
V0> Stage drop out ratio
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
52 / 70
B
INT
100% Stator Earth Fault Protection (ANSI 64G)
The 100 % stator earth fault protection detects earth faults in the stator windings of generators which
are connected with the network via a unit transformer. This protection function, which works with a 20
Hz injected voltage, is independent of the network frequency displacement voltage appearing in earth
faults, and detects earthfaults in all windings including the generator starpoint. The measuring principle
used is not influenced at all by the generator operating mode and would allow measurements even with
the generator at standstill (for personal safety reasons the voltage injection and the 100% SEF are
blocked if the turbine speed is below turning speed). The two measuring principles – measurement of
the displacement voltage and evaluation of the measured quantities at an injected 20 Hz voltage –
allow to implement reliable protection concepts that complement one another.
If an earth fault in the generator starpoint or close to the starpoint is not detected, the generator would
be operated as "earthed". A subsequent fault (e.g. a second earth fault) causes a single-pole shortcircuit that may have an extremely high fault current because the generator zero impedance is very
small.
The 100 % stator earth fault protection is for this reason a basic function for large generators in unit
connection.
Functional Description
The basic principle is shown in the following figure. An external low frequency alternating voltage
source (20 Hz) injects into the generator starpoint a voltage of max. 1 % of the rated generator voltage.
If an earth fault occurs in the generator starpoint, the 20 Hz voltage drives a current through the fault
resistance. From the driving voltage and the fault current, the protective relay determines the fault
resistance. The protection principle described here also detects earth faults at the generator terminals,
including connected components such as voltage transformers.
To implement the above concept, some additional equipment is required. The following picture shows
a 20 Hz generator creating a square-wave voltage with an amplitude of approx. 25 V. This squarewave voltage is fed via a bandpass into the loading resistor of the earthing or neutral transformer. The
bandpass serves for smoothing the square-wave voltage and for storing energy. The 20 Hz resistance
of the bandpass is approx. 8 Ω .The bandbass assumes also a protection function. If the load resistor
carries the full 50/60 Hz displacement voltage during a terminal-to-earth fault, the higher series
resistance of the bandpass protects the 20 Hz generator from excessive feedback currents.
The driving 20 Hz voltage is taken directly at the loading resistor using a voltage divider. In addition the
flowing 20 Hz current is measured using a miniature CT. Both values (USEF and ISEF) are fed to the
protection device.
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
53 / 70
B
INT
100% Stator Earth Fault Protection (ANSI 64G)
Settings
Symbol
UNM
Value
15.00
kV
Nominal machine voltage
SNM
74.14
MVA
Nominal machine apparent power
PNM
63.02
MW
Nominal machine active power
cosφ
0.85
UN NT prim
15.00
UN NT sec
tNT
10
s
Ratio VD
5
V
Ratio CT
/ √3
500
100
Nominal earthing transformer voltage (primary)
2
Nominal earthing transformer voltage (secondary)
A Overload capacitiy of the earthing transformer
V Ratio of voltage divider
5
5
10
Power factor
kV
V
200
RLoad
tLoad
Comments
Ratio of CTprim / CTsec on secondary side of earthing transformer
Ω
s
100
Resistance of the load resistor
A Overload capacitiy of the load resitor
ILoad max
UN NT sec
RLoad
=
=
UN NT prim
VDRatio
=
FACTOR R SES = TrRatio² *
CTRatio
UN NT sec
R< SEF ALARM =
500 V
5.0 Ω
=
100
A
²
VDprim
15.0 kV
²
VDsec
√3
*
=
*
CTprim
500 V
CTsec
4 kΩ
=
FACTOR R SES
V
V
5
2
40
4 kΩ
18.75
≈
213.3 Ω
1.33 kΩ
1.33 kΩ
=
FACTOR R SES
18.75
≈
70.93 Ω
=
18.75
Setting: standard fault resistance between 3 .. 6 kΩ
R<< SEF TRIP
=
Setting: standard fault resistance between 0.75 .. 2 kΩ
I(RMS)> = 0.20 *
T I(RMS)>
<
tRLoad
UN NT sec
1
500 V
5
*
= 0.20 *
*
RLoad
CTRatio
5.0 Ω
200
&
<
tNT
=
<
10
s
&
Ident-No.
<
10
= 0.50 A
s
=
0-76620-BB2284A-30
<
5
Sheet
Blatt
Revision
Classification
s
54 / 70
B
INT
100% Stator Earth Fault Protection (ANSI 64G)
The Threshold value of .3 I(RMS)> stage acts as a backup function of the 20 Hz SEF detecting the
50/60 Hz component measured in the load resistor.
General
Address
Parameter
Setting Options
Presetting
Values
Comments
.106
I20< supervision
5…40 mA
10 mA
10
mA
Superv. Threshold of 20Hz Cur.
.107
V20< supervision
0.300…14.723 V
1.732 V
1.000
V
Superv. Threshold of 20Hz Volt.
Correction Angle I SEF 100%
.101
Correction angle
-60.00 … 60.00 °
0.00 °
0.00
°
.103
Transf. Resistance (sec)
0.000 … 700.000 Ω
0.000 Ω
0.00
Ω
.110
Sec./Prim. factor R
1.00 … 200.00
37.00
18.75
.1
RL-parallel
activate
yes
.104
RL-parallel (sec)
20.000 … 70.000 Ω
20.000 Ω
20.000
.15
Corr. factor RL
-0.100 … 0.100
0.000
0.00
Setting Options
Presetting
Values
Comments
on
on
Stage must be activated
no
no
If yes - stage has reporting effect
only.
no
Resistance Rps (sec)
1)
Sec./Prim. factor RSGF
no
no
Parallel Load Resistance
Ω
2)
Parallel Load Resistance (sec) 2)
Correction for RI-PARALLEL 2)
R(20Hz) <
Address
Parameter
.1
Mode
.2
Operate & flt.rec.
blocked
on
off / test
yes
no
percent
.3
.6
Threshold
Operate delay
4.000
%
secondary
213.333
Ω
primary
4000.000
Ω
10.00
s
Pickup Value Alarm Stage Rsef<
0.00 … 300.00 s
10.00 s
Setting Options
Presetting
Values
Comments
on
on
Stage must be activated
no
no
If yes - stage has reporting effect
only.
Delay of Alarm Stage Rsef<
R(20Hz) <<
Address
Parameter
.1
Mode
.2
Operate & flt.rec.
blocked
yes
percent
1.330
%
.3
Threshold
secondary
70.933
Ω
1330.000
Ω
.6
Operate delay
0.00 … 300.00 s
10.00
s
on
off / test
no
primary
10.00 s
Ident-No.
Pickup Value Trip Stage Rsef<<
Delay of Trip Stage Rsef<<
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
55 / 70
B
INT
100% Stator Earth Fault Protection (ANSI 64G)
I (RMS) >
Address
Parameter
.1
Mode
.2
Operate & flt.rec.
blocked
1)
Setting Options
on
off / test
yes
no
.3
Threshold
secondary
.6
Operate delay
0.00 … 300.00 s
Presetting
Values
Comments
on
on
Stage must be activated
no
no
If yes - stage has reporting effect
only.
1.00 s
0.50
A
Pickup Value of I (RMS)> Stage
5.00
s
Delay of Stage I(RMS)>
... the final pickup value has to be determined in primary tests during commissioning
2)
... For power units with 20 Hz source connected via the neutral transformer in the generator starpoint, the protection
measures the loading resistance on the line side. If GCB is closed, some additional loading equipment on the LV-side of unit
transformer may influence the measuring. This parameter allows an additional loading resistance to be set, so that this is not be
mistaken for an earth resistance. The active power-dependent influence of the parallel load resistance can be taken into
account with a correction factor. The value can be determined during commissioning only.
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
56 / 70
B
INT
Rotor Earth Fault Protection R, fn (ANSI 64R)
Rotor earth fault protection is used to detect earth faults in the excitation circuit of the synchronous
generator. One earth fault in the rotor winding does not cause immediate damage; however, if a
second earth fault occurs, then this represents a winding short-circuit of the excitation coil. Magnetic
unbalances can occur resulting in extreme mechanical forces (high vibrations), which can lead to the
destruction of the machine.
Functional Description
The rotor earth fault protection in the 7UM85 uses an external system frequency auxiliary voltage of
approximately 36 to 45 V AC, which can be taken e.g. from the voltage transformers via a coupling unit
7XR81 or 7XR61. This voltage is symmetrically coupled to the excitation circuit and simultaneously
connected to the measurement input UE of the device provided for this purpose. The capacitors Ccoup
of the 7XR81/ 7XR61 coupling unit are protected by series resistors Rpre.
The rotor earth fault protection calculates the complex earth impedance from the auxiliary AC voltage
URE and the current IRE. The earth resistance RE of the excitation circuit is then calculated from the
earth impedance. The coupling capacitance of the coupling unit Ccoup, the series resistance Rpre
including the brush resistance, and the earth capacitance of the excitation circuit CE are also
considered. This method ensures that even relatively high-ohmic earth faults (up to 30 kΩ under ideal
conditions) can be detected.
Settings
Symbol
Value
Comments
UN VT sec
100
V
Nominal voltage of voltage transformers (secondary)
fN
50
Hz
Nominal grid frequency
Rpre
2x
Ccoup
2x
99 Ω
4 µF
Preresistance of 7XR61 (2 parallel connected series resistors)
Coupling capacity
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
57 / 70
B
INT
Rotor Earth Fault Protection R, fn (ANSI 64R)
R SERIES
X COUPLING =
R SERIES =
I RE<
=
1
2π * f * CCOUP
Rpre
=
+ Rbrush =
1
=
2π * 50 Hz * 8 µF
99
Ω
1
+
2
Ω
=
397.9 Ω
50
Ω
Umin
X COUPLING + R SERIES + ZE
Umin
=
X COUPLING + R SERIES +
1
1
1
2π * f * CE Rot
+
1
RE Rot
25 V
=
=
1
397.9 Ω
+
50.0
Ω
+
1
1
+
2π * 50 Hz * 0.10 µF
1.964 mA
1
20 kΩ
General
Address
Parameter
.109
Supervision
1)
Setting Options
on
off
Presetting
Values
on
on
Comments
.106
I< supervision
1.0…50.0 mA
2.0 mA
2.0
mA
.101
Correction angle
-1500 … 1500.00 °
0.00 °
0.00
°
Superv. Threshold of I<
Correction angle for Ire 1)
.103
X-coupling
-100 … 800 Ω
398 Ω
398
Ω
Coupling Reactance
.104
R-coupling
0 … 999 Ω
50 Ω
50.00
Ω
Series Resistance
.108
V-RGF external
source
yes
no
no
no
If coupling unit 7XR81 / 7XR61 is
used setting must be "no".
… measuring of any angle errors of the input CTs of the device
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
58 / 70
B
INT
Rotor Earth Fault Protection R, fn (ANSI 64R)
R<
Setting Options
Presetting
Values
Comments
off
on
R< Stage must be activated
yes
no
If yes - stage has reporting effect
only.
Address
Parameter
.1
Mode
.2
Operate & flt.rec.
blocked
yes
.3
Threshold
1.0 … 30.0 kΩ
10.0 kΩ
3.0
kΩ
.6
Operate delay
0.00 … 60.00 s
10.00 s
1.00
s
R< Operate Time delay
.7
Dropout delay
0.00 … 60.00 s
0.00 s
0.00
s
To avoid chattering
Address
Parameter
Setting Options
Presetting
Values
.1
Mode
off
on
R<< Stage must be activated
.2
Operate & flt.rec.
blocked
yes
no
no
If yes - stage has reporting effect
only.
.3
Threshold
1.0 … 30.0 kΩ
2.0 kΩ
1.0
kΩ
.6
Operate delay
0.00 … 60.00 s
0.50 s
1.00
s
R<< Operate Time delay
.7
Dropout delay
0.00 … 60.00 s
0.00 s
0.00
s
To avoid chattering
on
off / test
no
Pickup Value Warn. Stage R<
2)
R< <
2)
on
off / test
no
Comments
Pickup Value Trip. Stage R<< 2)
… values can be changed depending on the insulation resistance and the coolant
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
59 / 70
B
INT
Trip Circuit Supervision (ANSI 74TC)
The 7UM85 multifunctional protection features an integrated trip circuit supervision. Monitoring is
realized with the two binary inputs. Malfunctions in the trip circuit can be detected for all circuit breaker
positions.
Functional Description
The conditions of the two binary inputs are checked periodically. A query takes place about every 600
ms. If three consecutive conditional checks detect an abnormality (after 1.8 s), an annunciation is
reported. The repeated measurements determine the delay of the alarm message and avoid that an
alarm is output during short transition periods. After the fault in the trip circuit is removed, the alarm is
reset automatically after the same time.
Monitoring with Two Binary Inputs
When using two binary inputs, these are connected according to the figure below, parallel to the
associated trip contact on one side, and parallel to the circuit breaker auxiliary contacts on the other.
Monitoring with binary inputs not only detects interruptions in the trip circuit and loss of control voltage,
it also monitors the response of the circuit breaker using the position of the circuit breaker auxiliary
contacts.
Address
Parameter
.1
Mode
.100
Alarm delay
Setting Options
on
off / test
1.00 … 30.00 s
Presetting
Values
Comments
on
on
Stage must be activated
2.00 s
2.00
s
Ident-No.
Delay of Alarm Stage
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
60 / 70
B
INT
Out-of-Step Protection (ANSI 78)
Depending on power network conditions and feeding generators, dynamic occurrences such as load
jumps, short-circuits not disconnected quickly enough, auto-reclosure or switching actions may cause
system swings. Such power swings endanger power network stability. Stability problems often result
from active power swings which can lead to pole-slipping and generator overloading.
Functional Description
The out-of-step protection is based on the well-proven impedance measurement and evaluation of the
complex impedance vector trajectory. The decision whether or not to separate the generator from the
network is made dependent on the course of the impedance vector and the location of the electrical
centre of the power swing.
δ is the phase shift angle between the generator voltage and the network equivalent voltage. Under
normal conditions, this angle depends on the load situation and is largely constant. In the event of an
out-of-step condition, however the angle fluctuates continually and can vary between 0° and 360°. The
following figure shows the impedance vector trajectory at measurement location m. The coordinate
system origin corresponds to the measurement location (voltage transformer set). When the ratio of
the voltage magnitudes VNet/VG is kept constant and the load angle δ varies, then circular trajectories
result. The centre and the radius of the circle are determined by the ratio VNet/VG. The centre points of
the circles are all on an axis line which is determined by the direction of Ztot. Minimum and maximum of
the measured impedance magnitude are at δ = 0° and δ = 180°. If the measurement location is at the
electrical system centre, measured voltage and thus measured impedance become zero when δ =
180°.
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
61 / 70
B
INT
Out-of-Step Protection (ANSI 78)
Settings
Symbol
UNM
15.00
Value
INM
xd'
Comments
kV
Nominal machine voltage
2854
A
Nominal machine current
24.9
%
Transient machine reactance (unsaturated)
Ratio CT
4000
A
1
A Ratio of current transformer
Ratio VT
15000
V
100
V Ratio of voltage transformer
UNT
15
kV
SNT
73
MVA
Nominal transformer apparent power
uSC
0.132
pu
Transformer reactance on generator MVA base
xGrid
0.0303
pu
Grid reactance on generator MVA base
(R/X)Grid
0.125
pu
Grid R/X ratio
Nominal transformer voltage (generator side)
As out-of-step conditions are symmetrical occurrences, unsymmetrical componets of current shoud
block the out-of-step protection function. Thus if the positive sequence component of the current drops
below this parameter .101 I1< threshold blocks zone out-of-step protection should be blocked. A
threshold of approx. 20 % IN is recommended. If the negative sequence component of the current is
above parameter .100 I2> threshold blocks zone out-of-step protection should also be blocked. A
threshold of approx. 20 % IN is recommended.
Xd'sec = =
XTr sec
=
XGrid sec =
CTRatio
xd' * UNM
=
*
VTRatio
√3 * INM
0.249 * 15.00 kV
4000 A / 1
A
*
√3 * 2854 A
15000 V / 100 V
=
20.15 Ω
uSC * UNM
CTRatio
=
*
√3 * INM
VTRatio
0.132 * 15.00 kV
4000 A / 1
A
*
√3 * 2854 A
15000 V / 100 V
=
10.68
Ω
0.030 * 15.00 kV
A
4000 A / 1
*
15000 V / 100 V
√3 * 2854 A
=
2.45
Ω
xGrid * UNM
CTRatio
*
=
√3 * INM
VTRatio
As it is assumed that the generator is connected to the network via a unit transformer, the setting in the
network direction is chosen such that the out-of-step protection measures with characteristic Zone 1
approximately 90 % of the transformer impedance, and with characteristic Zone 2 right into the network.
Zone 1 parameters with: .104 Zone limit X top is set to 90 % of the short circuit impedance XTr of the
transformer and .105 Zone limit X bottom is set to negative value of generator Xd`.
Z1 .105 Zone limit X bottom
≈
Z1 .104 Zone limit X top
= 0.90 *
Xd'sec
=
20.15
XTr sec
Ω
= 0.90 * 10.68 Ω
=
9.61
Ω
For Zone 2 .104 Zone limit X top is the remaining portion of the transformer short circuit impedance
and the impedance of the grid is set (assuming that whole grid impedance is monitored). For very strong
grids with very low impedance twice the transformer reactance shall be considered. For that reason twice
of the transformer reactance (Zd1) is compared with the transformer reactance added by the grid
reactance (Zd2) and the higher value is selected as Zd.
Zd1
=
XTr sec
+
XTr sec
=
10.68 Ω
+
10.68 Ω
=
21.36
Ω
Zd2
=
Xgrid sec
+
XTr sec
=
2.45
Ω
+
10.68 Ω
=
13.13
Ω
MAX [Zd1 ; Zd2]
=
9.61
Ω
Z2 .104 Zone limit X top
=
21.36
Z2 . 105 Zone limit X bottom = Z1 .104 Zone limit X top
Ω
=
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
62 / 70
B
INT
Out-of-Step Protection (ANSI 78)
The angle .102 Rotation angle can be calculated as tan(φP)=Xges / Rges. In case the R/X ratio of the
grid is not known the restistance will be neglected and thus the angle will be estimated with 90°.
R/X
=
2.45
Ω * 0.13 =
Xgrid sec + XTr sec + Xd'sec
=
2.45
Ω + 10.68 Ω + 20.2
Rges = Rgrid =
Xges =
tan(φP) =
Xgrid sec *
0.31
Xges
Rges
Ω
φP =
Ω
=
89.5
33.29
Ω
°
The setting .103 Zone limit R effects the width of the power swing polygon. This setting value is
determined by the total impedance Ztot and can be derived from the equation in the figure below. The
default setting of address .103 Zone limit R corresponds to Ztot as the sum of generator xd` and Zd
(power swing angle between generator, unit transformer and grid). For simplification, it is assumed that
a power swing angle δ = 120° is strived for and since the generator voltage VG and the system voltage
UN are quantatively the same:
Z1 & Z2:
.103 Zone
limit R
=
( 20.15
=
Ω
Ztot / 2
tan ( δ / 2)
=
( xd` + Zd ) / 2
tan ( 120° / 2)
+ 21.36 Ω ) / 2
tan (60°)
11.98 Ω
=
General
Address
Parameter
Setting Options
Presetting
.101
I1< threshold
10 … 400.0 %
20 %
20.0
%
I1< threshold blocks zone
.100
I2> threshold
5 … 500.0 %
20 %
20.0
%
I2> threshold blocks zone
Values
Comments
Zone 1
on
.1
Mode
.2
Operate & flt.rec.
blocked
yes
.103
Zone limit R
secondary
off / test
no
on
on
Stage Zone 1 must be activated
no
no
If yes - stage Zone 1 has reporting
effect only.
percent
%
10.000 Ω
primary
11.985
Ω
0.450
Ω
percent
.104
Zone limit X top
secondary
%
10.000 Ω
primary
.105
.102
9.614
Ω
0.361
Ω
percent
Zone limit X
bottom
secondary
Rotation angle
60.0 … 90.0 °
Setpoint for the upper X value
%
-10.000 Ω
primary
exit
Width of the power swing polygon
90.0 °
-20.151
Ω
-0.757
Ω
89.5
°
Rotation Angle of Zone 1
This parameter defines when the
counter is incremented.
.108
Count at
.107
Number of swings
1 … 20
1
1.0
-
Number of swings before tripping
.101
Re-entry time
0.00 … 60.00 s
20.00 s
20.00
s
To define resetting condition
.100
Signal time
0.00 … 60.00 s
0.05 s
0.05
s
For binary indication purpose only
axis, entry, etc.
exit
Setpoint for the lower X value
exit
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
63 / 70
B
INT
Out-of-Step Protection (ANSI 78)
Zone 2
Address
Parameter
.1
Mode
.2
Operate & flt.rec.
blocked
Setting Options
on
off / test
yes
no
Presetting
Values
Comments
on
on
Stage Zone 2 must be activated
no
no
If yes - stage Zone 2 has reporting
effect only.
percent
.103
Zone limit R
secondary
%
10.000 Ω
primary
11.985
Ω
0.450
Ω
percent
.104
Zone limit X top
secondary
%
10.000 Ω
primary
Zone limit X
bottom
secondary
.102
Rotation angle
60.0 … 90.0 °
.108
Count at
.107
Number of swings
.101
.100
21.365
Ω
0.802
Ω
percent
.105
axis, entry, etc.
Setpoint for the upper X value
%
-10.000 Ω
primary
exit
Width of the power swing polygon
90.0 °
9.614
Ω
0.361
Ω
89.5
°
exit
Setpoint for the lower X value
Rotation Angle of Zone 2
This parameter defines when the
no. of swings is incremented.
exit
1 … 20
1
4.0
-
Re-entry time
0.00 … 60.00 s
20.00 s
20.00
s
To define resetting condition
Signal time
0.00 … 60.00 s
0.05 s
0.05
s
For binary indication purpose only
Ident-No.
Number of swings before tripping
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
64 / 70
B
INT
Frequency Protection (ANSI 81)
The frequency protection function detects abnormally high and low frequencies in the generator. If the
frequency lies outside the permissible range, appropriate switching actions are initiated, e.g. separating
the generator and the turbine from the system.
Functional Description
Frequency protection consists of the four frequency elements f< to f>. To make protection flexible for
different power system conditions, theses stages can be used alternatively for frequency decrease or
increase separately, and can be independently set to perform different control functions. The setting
decides on the purpose of the individual frequency stage.
Settings
Symbol
UNM
Value
15.00
Ratio VT
15000
V
Comments
kV
Nominal machine voltage
100
V Ratio of voltage transformer
fN
50.00
Hz
Nominal network frequency
f<<<
47.0
Hz
Threshold for shutdown
f<<
47.4
Hz
Threshold for disconnection from the network
f<
49.5
Hz
Threshold for warning
f>
52.5
Hz
Threshold for alarm or tripping
T f<
10.00
s
Time delay for warning
T f<<
3.00
s
Time delay for disconnection from the network
T f<<<
5.00
s
Time delay for shutdown
T f>
10.00
s
Time delay for alarm or tripping
The frequency can be determined as long as at least one of the phase–to–phase voltages is present
and of sufficient magnitude. If the measurement voltage drops below a settable value Umin .101
Minimum voltage, frequency protection is disabled because precise frequency values can no longer
be calculated from the signal.
Umin =
0.375 * UNM * UN VT sec
UN VT prim
=
0.375 * 15.00 kV * 100 V
= 37.5 V
15.00
kV
The following frequency pickup and time settings are coordinated with the generator and the turbine.
For steam turbines the over frequency initiates ALARM only, under frequency is used for ALARM, load
shedding and finally complete machine trip.
Underfrequency
General
Address
.101
.109
Parameter
Minimum voltage
Dropout differential
Setting Options
Presetting
percent
37.50 %
Values
Comments
37.500
%
secondary
37.500
V
primary
5.625
kV
20
mHz
20 … 2000 mHz
20 mHz
Ident-No.
For undervoltage blocking, 37.5 %
of rated voltage is recommended.
Dropout differential frequency
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
65 / 70
B
INT
Frequency Protection (ANSI 81)
f<
Address
Parameter
Setting Options
.1
Mode
.2
Operate & flt.rec.
blocked
yes
.3
Threshold
30.00 … 70.00 Hz
49.80 Hz
49.50
Hz
f< Threshold Warning
.6
Operate delay
0.00 … 600.00 s
10.00 s
10.00
s
Time delay for f< Warning
Address
Parameter
Setting Options
Presetting
Values
Comments
.1
Mode
on
on
Stage f<< must be activated
.2
Operate & flt.rec.
blocked
yes
no
no
If yes - stage f<< has reporting
effect only.
.3
Threshold
30.00 … 70.00 Hz
47.50 Hz
47.40
Hz
f<< Threshold disconnecting grid
.6
Operate delay
0.00 … 600.00 s
10.00 s
3.00
s
Time delay for f<< stage
Address
Parameter
Setting Options
Presetting
Values
Comments
.1
Mode
on
on
Stage f<<< must be activated
.2
Operate & flt.rec.
blocked
yes
no
no
If yes - stage f<<< has reporting
effect only.
.3
Threshold
30.00 … 70.00 Hz
47.50 Hz
47.00
Hz
Gen.CB open, deexitation, trip
.6
Operate delay
0.00 … 600.00 s
10.00 s
5.00
s
Time delay for f<<< shut down
on
off / test
no
Presetting
Values
Comments
on
on
Stage f< must be activated
no
no
If yes - stage f< has reporting
effect only.
f <<
on
off / test
no
f <<<
on
off / test
no
Overfrequency
General
Address
Parameter
Setting Options
Presetting
percent
37.50 %
37.500
%
.101
Minimum voltage
secondary
37.500
V
primary
5.625
kV
20
mHz
.109
Values
Comments
For undervoltage blocking, 37.5 %
of rated voltage is recommended.
Dropout differential
20 … 2000 mHz
20 mHz
Address
Parameter
Setting Options
Presetting
Values
Comments
.1
Mode
on
on
Stage f> must be activated
.2
Operate & flt.rec.
blocked
yes
no
no
If yes - stage f> has reporting
effect only.
.3
Threshold
30.00 … 70.00 Hz
49.80 Hz
52.50
Hz
f> Threshold Warning
.6
Operate delay
0.00 … 600.00 s
10.00 s
10.00
s
Time delay for f> Warning
Dropout differential frequency
f>
on
off / test
no
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
66 / 70
B
INT
Differential Protection (ANSI 87G)
The numerical current differential protection of the 7UM85 is a high speed selective short-circuit
protection for generators, motors and transformers. The protected zone is selectively limited by the
CTs at its ends.
Functional Description
Since the current direction is normally defined as positive in the direction of the protected object, the
definitions as illustrated in the following figure result. The protected zone is limited by the CTs in the
neutral point of generator and the CTs at the terminal side. The differential protection feature of the
7UM85 refers all currents to the rated current of the protected object. Measured value matching is
therefore limited to current quantity factors.
Settings
Symbol
Value
Comments
UNM
15.00
kV
Nominal machine voltage
INM
2854
A
Nominal machine current
xd'
22.4
%
Related transient machine reactance (saturated)
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
67 / 70
B
INT
Differential Protection (ANSI 87G)
Tripping characteristic
The parameters of the tripping characteristic are set in addresses .1 up to .130. The meaning of the
parameters can be seen in the figure above.
Address .3 Threshold (I-DIFF) is the pickup value for the differential current which is the total fault
current flowing in the protection area. The pickup value is referred to the nominal current of the
generator or motor. For generators, a setting of 0.2 is recommended.
In addition to the pickup threshold I-DIFF>, a second pickup threshold is introduced. If this threshold
.3 Threshold (I-DIFF fast) is exceeded, tripping is initiated regardless of the magnitude of the restraint
current (unstabilized high-speed trip stage). This stage must be set higher than the I-DIFF> stage.
Recommendation: Set a value above the steady-state value of the transient short-circuit current.
I-DIFF fast
=
1
xd'
=
1
0.2240
≈ 4.47
I
IrObj
The tripping characteristic forms two more branches (see the following figure). Address .100 Slope 1
determines the slope of the first branch, whose starting point is specified in the parameter .101
Intersection 1 Irest. This branch covers current-proportional error currents. These are mainly
transformation errors of the main CTs and of the input CTs. The default setting of 0.67 has proven to
be a good value.
The second branch produces a higher restraint in the range of high currents which may lead to current
transformer saturation. Its base point is set at address .103 Intersection 2 Irest and is referred to the
rated power transformer current. The slope 2 is set at address .102 Slope 2 . The restraint during
current transformer saturation can be influenced by this parameter branch. A higher gradient results in
a higher restraint. The default setting of 0.70 has proven to be an adequate value.
Add-On Stabilization During Current Transformer Saturation
Where very high currents flow during an external short-circuit, an add-on stabilization takes effect that
is set at address .128 Threshold add-on stabiliz. (saturation stabilization). Please note that the
stabilizing current is the arithmetical sum of the currents entering and leaving the protected zone, i.e.
that it is twice the actually flowing current. The default setting of 2.00 I/IrObj should therefore be kept.
The maximum duration of the additional stabilization is set at address .129 Time of add-on stabiliz .
This time is the maximum duration of blocking after leaving the additional stabilization area during
heavy current external faults. The setting depends under certain circumstances on the disconnecting
time of the upstream contact. The default setting 0.30 s is a practical value.
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
68 / 70
B
INT
Differential Protection (ANSI 87G)
I-DIFF
Address
Parameter
Setting Options
.1
Mode
.2
Operate & flt.rec.
blocked
.6
Operate delay
0.00 … 60.00 s
0.00 s
0.00
s
Time delay of I-DIFF
.3
Threshold
0.05 … 2.00 I/ IrObj
0.20 I/ IrObj
0.20
I/ IrObj
Pickup Value of Diff. Value
on
off / test
yes
no
Presetting
Values
Comments
on
on
I-DIFF Stage must be activated
no
no
If yes - stage has reporting effect
only.
.100
Slope 1
0.00 … 0.80
0.30
0.30
.101
Intersection 1 Irest
0.05 … 5.00 I/ IrObj
0.67 I/ IrObj
0.67
.102
Slope 2
0.25 … 0.95
0.70
0.70
.103
Intersection 2 Irest
1.00… 20.00 I/ IrObj
2.50 I/ IrObj
2.50
.106
Starting detection
.107
Thresh.startup detec
yes
no
0.1 … 2.0 I/ IrObj
yes
0.1 I/ IrObj
Slope 1 of Tripping Characteristic
I/ IrObj
Slope 2 of Tripping Characteristic
I/ IrObj
Increased pick-up values at startup
for motors only.
no
0.1
.108
Factor incr. char.
1.0 … 5.0
2.0
2.0
.109
Max perm. start time
0.1 … 180.0 s
5.0 s
5.0
I/ IrObj
I-Restraint for Start Detection
s
Max. permissable Starting Time
Factor for Incr. Char. at Start
.110
Factor incr. char DC
1.0 … 5.0
2.3
2.3
.128
Thresh.add-on stab
1.0 … 20.0 I/ IrObj
2.0 I/ IrObj
2.0
I/ IrObj
Pickup for Add-on Stabilization
.129
Time of add-on stab
0.00 … 5.00; ∞ s
0.30 s
0.30
s
Duration of Add-on Stabilization
.130
Max perm. start time
0.00 … 2.00; ∞ s
0.30 s
0.30
s
T for Cross-blocking Addon Stab.
Ident-No.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
69 / 70
B
INT
Differential Protection (ANSI 87G)
I-DIFF fast
Address
Parameter
.1
Mode
Setting Options
on
off / test
Presetting
Values
Comments
on
on
I-DIFF fast Stage must be activated
.3
Threshold
0.5 … 35.0 I/ IrObj
7.5 I/ IrObj
4.5
I/ IrObj
Pickup Value of Diff. fast Value
.6
Operate delay
0.00 … 60.00 s
0.00 s
0.00
s
Time delay of I-DIFF fast
.100
Operate & flt.rec.
blocked
yes
no
no
If yes - stage has reporting effect
only.
no
Overview of different stages
I-DIFF unrestrained detection:
The main task of this function consists in switching off high-current internal short circuits in the
shortest amount of time. Hight-current faults in the protection range can always be switched off
immediately without consideration of the restraint currents if, due to the current magnitude, it is
determined that external fault is not involved. This is the case if the parameter .3 Threshold I-DIFF
unrestr is reached as shown in picture below.
I-DIFF unrestr
Address
Parameter
.1
Mode
.3
Threshold
0.5 … 35.0 I/ IrObj
10.0 I/ IrObj
10.00
I/ IrObj
Pickup Value of Diff. unrestr Value
.6
Operate delay
0.00 … 60.00 s
0.00 s
0.00
s
Time delay of I-DIFF unrestr
Operate & flt.rec.
blocked
yes
.100
Setting Options
on
off / test
no
Presetting
Values
Comments
on
on
I-DIFF unrestr Stage must be
activated
no
no
Ident-No.
If yes - stage has reporting effect
only.
0-76620-BB2284A-30
Sheet
Blatt
Revision
Classification
70 / 70
B
INT