Substation Automation

(1)

SUBSTATION AUTOMATION

(FROM CONVENTIONAL SUBSTATION TO GSM/CDMA AUTOMATION SYSTEM)

PREPARED BY

GOPALA KRISHNA PALEPU

ADE/400KV/ VS/HYD

Mobile:9440336984

(2)

From substation control and protection to

Fibre optics based Substation.

Fibre optics based Substation to GSM /CDMA

based Substation Automation.

From modern to intelligent Substation

Automation

System Architectures

Functional Structures

Application examples

(3)

¾

IT based solution for protection and control offer cost

effective measures to counteract large area system

disturbances.

¾

Effective fault location is mandatory for faster finding

and fixing of problems.

¾

Integrated numerical protection & control allows

automated power restoration and load shedding.

¾

On-line condition monitoring reduces maintenance

costs and enables.

¾

Substation Automation offers a cost effective

infrastructure for implementing on-line condition

monitoring of assets.

¾

Voltage instability prediction is a new approach for

early indication voltage collapses and enables to

work plants and systems harder.

¾

Integrated asset management improves overall

(4)

General Principles of Substation Automation

The general principles of the substation operation have

not changed, since their developing days. Therefore the

control and protection tasks remain the same.

The objective of modern substation automation (SA) is to

solve these tasks in a more efficient and economical way

by using state of the art information technologies (IT) and

to provide more functionality to work plant and systems

harder.

(5)

CONVENTIONAL

SUBSTATION

PRACTICES

PREPARED BY

GOPALA KRISHNA PALEPU

ADE/400KV/ VS/HYD

Mobile:9440336984

(6)

CONVENTIONAL SUBSTATION

1. Very Wide Cabling. i.e. from equipment to BMB/CTMB/CVT MB and from BMB/CTMB/CVT MB to

Control Room Dedicated Device.

2. For each function Dedicated Device.

I. Bay Control – Control Panels for the Bay

Circuit Breaker Control & Indication.

Isolator Control & Indication.

Earth Switch Indication.

DC & AC Healthy Indication and Testing.

Annunciation facia for Troubles.

Panel Meters & Energy Meter.

II. Bay Protection – Relay & Protection Panels - Protective Relays of Concerned bay

Circuit Breaker Relay Panel (A/R, LBB, TSR, CB Troubles, Master Trip Relays etc).

Line Protection Panel (21L1, 21L2, 67, 59-1, 59-2, 50 Stub, 87 Teed-1, 87 Teed-2 etc).

ICT Protection Panel (87T1, 87T2, 67HV, 67IV, 50O/L, 99HV, 99IV etc).

Reactor Protection Panel (87R, 64R, 21R, 87Teed-1, 87Teed-2 etc).

III. Bus Bar Protection – Entire Substation Protection - Each Voltage Level Bus Bar Protection Panels

High Impedance Bus Bar Protection With Main & Check Panels for each Bus.

Medium Impedance Bus Bar Protection Panels for each Bus.

Low Impedance Bus Bar Protection Panels for Each Bus.

Numerical Bus Bar Protection Panels for Centralised or Distributed Architecture.

Redundant Numerical Bus Bar Protection for each Voltage Level.

III. Fault Recorder – Disturbance Recorder - For each Bay stand alone Disturbance Recorder

Line, Transformer/ICT, Reactor & Bus bar

III. Event Recorder – SOE / EL / ER for all Bays

The Operation of all Equipments & Protective relays will be shown in a sequence with

millisecond resolution. This is Time Synchronised with GPS.

IV. RTU – Remote Terminal Unit

(7)

CONVENTIONAL CONTROL & PROTECTION

Process

L

evel

Bay

L

evel

Station Level

GIS or AIS

Switchgear

1-89B ISO

1-52 CB

1-89L ISO

1-89LE ES

1-89A ISO

1 3 8 =D04+R01 225kV LIGNE ABOBO 1 ABB

125VDC Distributuion Battery A125VDC Distributuion Battery B

Fault

Recording

Ind actic 650 In dactic 6 50 Inda ctic 650

=D04+R01 225kV LIGNE ABOBO 1 ABB

125VDC Distributuion Battery A125VDC Distributuion Battery B BAY CONTROL RELAY REC316*4

1

ABBABB Network Partner

REL316*4

2435678912111314151610

LOCAL CONTROL METERING LINE PROTECTION RELAY REL316*4

1

ABBABB Network Partner REL316*4 2435678912111314151610

BUSBAR PROTECTION REB500 ABB

ABB Network Partner REB500

-Q1 =W1 =W2 FERMER 12345678910111213141516 cc Veriosn4.2b

Bay Protection

Local

Marshalling

Boxes

Busbar Protection

SCADA

RTU

RTU 200IN 1 IN 2 IN 3 IN 4 IN 5 IN 6 IN 7 IN 8 OUT ON/OFF RTU 200IN 1 IN 2 IN 3 IN 4 IN 5 IN 6 IN 7 IN 8 OUT ON/OFF RTU 200IN 1 IN 2 IN 3 IN 4 IN 5 IN 6 IN 7 IN 8 OUT ON/OFF

Indactic 650 Indactic 650 Indactic 650 Indactic 650

Event

Recording

Bay

Control

=D04+R01 225kV LIGNE ABOBO 1 ABB ABB -Q2 SEL -Q1 SEL -Q0 SEL =W1 =W2 FERMER OUVRIR EXE ESC LAMPE TESTE DISTANCE LOC ABB ABB ABB

1-CT

1-CVT

(8)

SUBSTATION

MONITORING

SYSTEM

(Next Development)

PREPARED BY

GOPALA KRISHNA PALEPU

ADE/400KV/ VS/HYD

Mobile:9440336984

(9)

SUBSTATION MONITORING SYSTEM

1. Still Very Wide Cabling. i.e. from equipment to BMB/CTMB/CVT MB and from BMB/CTMB/CVT MB to

Control Room Dedicated Device.

2. For each function Dedicated Device and some functions are Integrated due to Numerical Advantage.

I. Bay Control – Control Panels for the Bay

Circuit Breaker Control & Indication.

Isolator Control & Indication.

Earth Switch Indication.

DC & AC Healthy Indication and Testing.

Annunciation facia for Troubles.

Panel Meters & Energy Meter.

II. Bay Protection – Relay & Protection Panels - Protective Relays of Concerned bay

Circuit Breaker Relay Panel (A/R, LBB, TSR, CB Troubles, Master Trip Relays etc).

Line Protection Panel (21L1, 21L2, 67, 59-1, 59-2, 50 Stub, 87 Teed-1, 87 Teed-2 etc).

ICT Protection Panel (87T1, 87T2, 67HV, 67IV, 50O/L, 99HV, 99IV etc).

Reactor Protection Panel (87R, 64R, 21R, 87Teed-1, 87Teed-2 etc).

III. Bus Bar Protection – Entire Substation Protection - Each Voltage Level Bus Bar Protection Panels

Numerical Bus Bar Protection Panels for Centralised or Distributed Architecture.

LBB is part of Bus Bar Protection

Redundant Numerical Bus Bar Protection for each Voltage Level.

III. Fault Recorder – Disturbance Recorder - For each Bay stand alone Disturbance Recorder

Line, Transformer/ICT, Reactor & Busbar – Part / Inbuilt Function of Numerical Relays

III. Event Recorder – SOE / EL / ER for all Bays – Inbuilt function of Numerical Relays

IV. RTU – Remote Terminal Unit

For Balance Events not Covered by Protective relays are wired to RTU.

V. All are connected to System and from system to communication Media to ALDC

VI. FBS – Fall Back Switch – FSK/NSK Modem.

(10)

SUBSTATION MONITORING SYSTEM

Process

L

evel

Bay

L

evel

Station Level

GIS or AIS

Switchgear

1-89B ISO

1-52 CB

1-89L ISO

1-89LE ES

1-89A ISO

Bay Protection

Local

Marshalling

Boxes

Busbar Protection

Bay

Control

1-CT

1-CVT

BMB/BMK/SyMB

CVT MB/JB

CT MB/JB

Interbaybus

Star coupler

d gi t al

Tx2 Rx1 Tx1 500SCM 01 Rx3 Tx3 Rx2 Tx2 Rx1 Tx1

di gi t al

NCC / RCC

SCADA- SMS

ABB

Power Automation AG COM581 C

Communication

Converter

ABB

Power Automation AG

RER111

500SCM 01 Rx3 Tx3 Rx2 Tx2 Rx1 Tx1 500SCM 01 Rx3 Tx3 Rx2 Tx2 Rx1 Tx1 500SCM 01 Rx3 Tx3 Rx2 Tx2 Rx1 Tx1 500SCM 01 Rx3 Tx3 Rx2

FBS

SCADA

RTU

1

ABB

ABB Network Partner REL316*4

2435678

9

121113141516

10

1

ABBABB Network Partner REL316*4

2435678

9

121113141516

10

BUSBAR PROTECTION REB500 ABB

ABB Network Partner REB500

-Q1 =W1 =W2 FERMER 12345678910111213141516 cc Veriosn 4.2b

(11)

COMMUNICATION:

LEVELS OF SUBSTATION CONTROL

& AUTOMATION

Switchgear

Control Centre Level

Process Level

Bay Level

(12)

SUBSTATION

AUTOMATION

SYSTEM

(Stage-1 Development)

PREPARED BY

GOPALA KRISHNA PALEPU

ADE/400KV/ VS/HYD

Mobile:9440336984

(13)

SUBSTATION AUTOMATION SYSTEM(STAGE-1)

1. This system is exciting Conventional System to convert Remote Control System.

2. This is same as Substation Monitoring System.

3. Additionally One More RTU is Provided for Remote Control & Operation.

4. Normally RTU Having 3 Types of cards

1. Analog Input Card - To Monitor the Analog Values

2. Digital Input Card – To Monitor the Status of Equipment

3. Digital Output Card – To Control & Operation of Substation Equipment

5. Exciting RTU for only Monitoring the Substation from Remote Control Station exclusively

for ALDC / SLDC / RLDC / NLDC.

6. Without disturbing the exciting RTU the following works are carried.

7. All Controls of Circuit Breakers & Isolators are Brought to RTU to Control Card.

8. All Status of Circuit Breakers & Isolators are Brought to RTU to Digital Card.

9. Each Bay is provided with Multifunction Meters. They are connected in Modbus

configuration and brought to network.

10. Transformer OTI, WTI, Online DGA & Tap Changer Positions information is available in

4-20mA. They are brought to RTU Analog Card.

11. Switch yard is fixing with no of Digital Cameras and focusing the major equipment to View

the yard and this is having a facility to slow motion moving round to cover all the Major

equipments. This also put in Network to Monitor from remote/ Local

12. The RTU, Energy Meters, MFM and Digital Cameras are connected in Network in Ethernet

Switch and to Station Control System and connected to Modem & Router to Remote

Control Center.

13. The Operator, those who are sitting at Remote control Center having a System and he

can Monitor the substation and take a decision for any thing.

(14)

SUBSTATION AUTOMATION SYSTEM (STAGE-1)

12345678910111213141516

Process

L

evel

Bay

L

evel

Station Level

GIS or AIS

Switchgear

1-89B ISO

1-52 CB

1-89L ISO

1-89LE ES

1-89A ISO

Bay

Protection

Local

Marshalling

Boxes

Bay

Control

1-CT

1-CVT

BMB/BMK/SyMB

CVT MB/JB

CT MB/JB

Interbaybus

Star coupler

d gi ta l

di gi t al

NCC / RCC

SCADA- SCS

ABB

Communication

Converter

ABB

Power Automation AG

RER111

500SCM 01 Rx3 Tx3 Rx2 Tx2 Rx1 Tx1 500SCM 01 Rx3 Tx3 Rx2 Tx2 Rx1 Tx1 500SCM 01 Rx3 Tx3 Rx2 Tx2 Rx1 Tx1 500SCM 01 Rx3 Tx3 Rx2

FBS

1

ABB

ABB Network Partner REL316*4

2435678

9121113141516

10

BUSBAR PROTECTION REB500 ABBABB Network Partner

REB500 -Q1 =W1 =W2 FERMER cc Veriosn4.2b

Busbar Protection

TO

ALDC / SLDC / RLDC

RTU

(15)

SUBSTATION

AUTOMATION

SYSTEM

(Stage-2 Development)

PREPARED BY

GOPALA KRISHNA PALEPU

ADE/400KV/ VS/HYD

Mobile:9440336984

(16)

SUBSTATION AUTOMATION SYSTEM(STAGE-2)

1. This system is adopted for New Substations, at the time of tendering.

2. This is same as Substation Monitoring System except new IED is introduced in a Panel. It is

called Bay Control Unit.

3. This Replaces additional one More RTU for Remote Control & RTU for ALDC / SLDC / RLDC /

NLDC as if it is new Substation.

4. The Bay Control Unit IED is one unit per Bay and it is Provided in CB Relay Panel.

5. This is almost RTU, but limited to one Bay and nothing but Mini RTU / Distributed RTU.

6. All Controls & Status of Circuit Breakers & Isolators and Circuit Breaker Troubles and Alarms

are Brought to BCU of Particular Bay in addition to Conventional Control Panel.

7. Each Bay is provided with Energy Meters &Multifunction Meters. They are connected in

Modbus configuration and brought to network. The control panel also having Panel Meters.

8. Transformer OTI, WTI, Online DGA & Tap Changer Positions information is available in

4-20mA. They are brought to BCU Analog Card.

9. Transformer Troubles and Alarms and are brought to BCU Digital Card.

10. Transformer Tap Changer Control is brought to BCU Control Card.

11. Switch yard is fixing with no of Digital Cameras and focusing the major equipment to View the

yard and this is having a facility to Move in slow motion, around the bay to cover all the Major

equipments. This also put in Network to Monitor from remote/ Local.

12. The Numerical IEDs , Energy Meters, MFM and Digital Cameras are connected in Network in

Ethernet Switch and to Station Control System and connected through Gateway to Remote

Control Center and ALDC / SLDC / RLDC / NLDC.

13. The Operator, those who are sitting at Remote control Center having a System and he can

Monitor the substation and take a decision for any thing.

14. This is Stage-2 Substation Control System.

(17)

SUBSTATION AUTOMATION SYSTEM (STAGE-2)

Process

L

evel

Bay

L

evel

Station Level

GIS or AIS

Switchgear

1-89B ISO

1-52 CB

1-89L ISO

1-89LE ES

1-89A ISO

Bay

Protection

Local

Marshalling

Boxes

Bay

Control

1-CT

1-CVT

BMB/BMK/SyMB

CVT MB/JB

CT MB/JB

Inter bay bus

Star coupler

NCC / RCC

SCADA- SCS

ABB

Communication

Converter

d gi t a l

di gi t al

ABB

Power Automation AG

RER111

500SCM 01 Rx3 Tx3 Rx2 Tx2 Rx1 Tx1 500SCM 01 Rx3 Tx3 Rx2 Tx2 Rx1 Tx1 500SCM 01 Rx3 Tx3 Rx2 Tx2 Rx1 Tx1 500SCM 01 Rx3 Tx3 Rx2 =D04+R01 225kV LIGNE ABOBO 1 ABB ABB -Q2 SEL -Q1 SEL -Q0 SEL =W1 =W2 FERMER OUVRIR EXE ESC LAMPE TESTE DISTANCE LOC ABB ABB ABB

Busbar Protection

TO

ALDC / SLDC / RLDC

1

BUSBAR PROTECTION REB500 ABBABB Network Partner

REB500 -Q1 =W1 =W2 FERMER 12345678910111213141516 cc Veriosn4.2b

?

LOCAL REMOTESET OPERATION M M M

Communication

Gate way

(18)

SUBSTATION

AUTOMATION

SYSTEM

(Stage-3 Development)

Distributed Control Room using Bay Kiosks or say

Portable Relay Rooms

PREPARED BY

GOPALA KRISHNA PALEPU

ADE/400KV/ VS/HYD

[email protected],

Mobile:9440336984

(19)

SUBSTATION AUTOMATION SYSTEM (STAGE-3)

1. This system is adopted for New Substations, at the time of tendering.

2. This is Distributed Control Rooms using Bay Kiosks and called Portable Relay Rooms.

3. In this Conventional Control Panel is not required.

4. The Bay Control Unit IED is one unit per Bay and it is Provided in CB Relay Panels for Control & Monitoring.

5. This is almost RTU, but limited to one Bay and nothing but Mini RTU.

6. All Controls & Status of Circuit Breakers & Isolators and Circuit Breaker Troubles and Alarms are Brought to

BCU of Particular Bay.

7. Each Bay is provided with Energy Meters &Multifunction Meters. They are connected in Modbus

configuration and brought to network.

8. Transformer OTI, WTI, Online DGA & Tap Changer Positions information is available in 4-20mA. They are

brought to BCU Analog Card.

9. Transformer Troubles and Alarms and are brought to BCU Digital Card.

10. Transformer Tap Changer Control is brought to BCU Control Card.

11. Switch yard is fixing with no of Digital Cameras and focusing the major equipment to View the yard and this

is having a facility to Move in slow motion, around the bay to cover all the Major equipments. This also put

in Network to Monitor from remote/ Local.

12. The Numerical IEDs , Energy Meters, MFM and Digital Cameras are connected in Network in Ethernet

Switch and to Station Control System and connected through Gateway to Remote Control Center and ALDC

/ SLDC / RLDC / NLDC.

13. The Operator, those who are sitting at Remote control Center having a System and he can Monitor the

substation and take a decision for any thing.

14. This is Stage-3 Substation Control System.

15. Still Extensive Wide cabling between Bay Kiosks/PRR to Switch yard equipment. But cables reduced to 60%

to 80%.

16. The Main Control Room Having only Network system with Printer and Aux System Monitoring.

17. But still Auxiliary system Location is Not Distributed and Centralised. This concept is not changing.

18. All IEDs are connected to Fibre Optic cable and Ethernet Switches. Even if FO cables damaged, still

protection function is working and it is unable to Monitor and control from Control Room / RCC / ALDC /

SLDC.

(20)

BAY LEVEL AUTOMATION (STAGE-3)

Interbay Bus

ABB Network Partner AG

C

E

COM581

Network Control

Center NCC

-Q1

-Q0

-Q9

-Q8

-Q2

Process

L

evel

Bay

L

evel

Station Level

125VDC Distributuion Battery A 125VDC Distributuion Battery B BAY CONTROL RELAY REC316*4

1

ABBABB Network Partner REL316*4 2435678 9

121113141516

10

1

BUSBAR PROTECTION REB500

ABBABB Network Partner REB500

ABB =D04 ABOBO 1 -Q2SEL -Q1SEL -Q0SEL =W1 =W2 FERMER OUVRIR EXE ESC LAMPETESTE DISTANCE LOC ABB

POWER MONITORING UNIT

?

(21)

BAY LEVEL AUTOMATION (STAGE-3)

Mainstream Hardware

Features

Mainstream Software platforms

Integrated SA System

• Control (BCU)

• Monitoring (BCU)

• Metering (BCU)

• Protection (BPU)

• DR (BPU)

• SOE / ER (BCU+BPU)

• Billing (TVM/EM)

• etc.

Open System

TCP / IP Ethernet communication

Using fibre optic media

for communication

Compact design

Decentralised system structure

closer to process

Distributed Control Rooms

Or called Bay Kiosks

Or called Portable Relay Rooms

No conventional mimic board

Less inventories and spare parts

Benefits

Less training & Familiarisation

Less Hardware and panels

Less operation and maintenance

costs

More availability

Minimising outage breaks

Integration of third-party

equipment

Less cabling and installation

costs

Less testing and commissioning

costs

(22)

HIGHLIGHTS BAY LEVEL SA

Features

Numerical Protection (BPU)

Numerical Control (BCU)

Benefits

Safe interlocking

Self supervision

Modern MMI / HMI

Operator guidance

Maintenance support

Easy to use and to customise

Efficient operation

• Avoiding errors

• Less hazards and breaks

• Reduction of operation costs

Increasing availability

Reducing maintenance costs

Higher power quality

(23)

ENHANCED FUNCTIONALITY OF BAY LEVEL SA

Features

Process status information

On-line Primary equipment

monitoring

Benefits

SA System status information

Events and Alarms evaluation

Disturbance records

Trends and calculations

Reports

Better planning

• more timely data

Efficient trouble shooting

All information at one glance

Better monitoring

Efficient asset management

Supports operation decisions

(24)

SUBSTATION

AUTOMATION

SYSTEM

(Stage-4 Development)

PROCESS LEVEL INTELLIGENT SUBSTATION

AUTOMATION

PREPARED BY

GOPALA KRISHNA PALEPU

ADE/400KV/ VS/HYD

[email protected],

Mobile:9440336984

(25)

SUBSTATION AUTOMATION SYSTEM (STAGE-4)

1. This system is adopted for New Substations, at the time of tendering.

2. This is Distributed IEDs for each Switch Yard Equipment for Operation and Maintenance.This is

Called Process Bus Automation.

3. Non Conventional Instrument Transformers for Voltage and Current Measurement .

4. In this Distributed Control Rooms / Bay Kiosks / Portable relay Rooms are not required.

5. One complete Panel for one Bay. All control, Protection IEDs TVM/EM are available.

6. No Physical wiring from Switch Yard to Bay to Control. Total Fibre Optic Ethernet connection and

IEC61850 Communication.

7. No Cable Trenches. No DC Leakage.

8. But Centralised Auxiliary System and Physical Cabling to all Bay switch yard equipment and relays

and other accessory systems.

9. Switch yard is fixing with no of Digital Cameras and focusing the major equipment to View the yard

and this is having a facility to Move in slow motion, around the bay to cover all the Major

equipments. This also put in Network to Monitor from remote/ Local.

10. The Numerical IEDs , Energy Meters, MFM and Digital Cameras are connected in Network in

Ethernet Switch and to Station Control System and connected through Gateway to Remote Control

Center and ALDC / SLDC / RLDC / NLDC.

11. The Operator, those who are sitting at Remote control Center having a System and he can Monitor

the substation and take a decision for any thing.

12. This is Stage-4 Substation Control System called Process Bus Substation Automation System.

13. Civil Engineering Cost in the yard reduces Drastically.

14. The Main Control Room Having only Network system with Printer and Aux System Monitoring.

15. But still Auxiliary system Location is Centralised, but Not Distributed. This concept is not changing.

16. Redundant, alternative communication channels are required to safe guard if FO cable damages.

17. The reliability of system Depends on availability of Fibre Optic System.

(26)

INTELLIGENT SA ARCHITECTURE

Network Control

Center NCC

Interbay Bus

ABB Network Partner AG

C

E

COM581

Process Bus

PI

S

A

PI

S

A

PI

S

A

B

PI

S

A

-Q1

-Q2

-Q51

-Q0

-T1

-Q9

-Q8

Process

L

evel

Bay

L

evel

Station Level

=D04+R01 225kV LIGNE ABOBO 1

ABB

1

121113141516 10

1

121113141516 10

ABB =D04 ABOBO 1 -Q2SEL -Q1SEL -Q0 SEL =W1 =W2 FERMER OUVRIR EXE ESC LAMPE TESTE DISTANCE LOC ABB

?

LOCAL REMOTE SET OPERATION M M M DISTANCE LOC

ABB POWER MONITORING UNIT

(27)

IMPLEMENTATION OF INTELLIGENT SAS

t

i i t l

Intelligent Primary Equipment

Interbay bus

Ethernet Switches

d gi tal

di gi t al

NCC / RCC

MicroSCADA

ABB

Communication

Converter

COM 581

-Q1

-Q0

-Q8

Feeder Marshalling

-Q9

-Q2

PISA

A

PISA

B

PISA

A

-Q1

-Q2

-Q51

-Q0

-T1

-Q9

-Q8

ABB

125VDC Distributuion Battery A 125VDC Distributuion Battery B

BAY CONTROL RELAY REC316*4

1

2 43 5678 9 1211 13141516 10

LOCAL CONTROL METERING

LINE PROTECTION RELAY REL316*4

1

2 43 5678 9 1211 13141516 10

ABB

=D04 ABOBO 1 -Q2 SEL -Q1 SEL -Q0SEL =W1 =W2 FERMER OUVRIR EXE ESC LAMPE TESTE DISTANCE LOC ABB

?

LOCAL REMOTE SET OPERATION M M M

Process

Bus

(28)

INTELLIGENT SAS

ABB

Inter bay bus 1

Inter bay bus 2

Phase L1

PISA

A

PISA

A

PISA

B

Abgangsschutz I

Feldleitgerät

Abgangsschutz II

Line Protection 1

Bay Controller

Line Protection 2

Bus Bar Protection

Star Coupler

Process Bus

Sensors for

current &

voltage

measurement

Actuator for

circuit breaker

control

Actuator for

isolator &

earthing

switch

control

=D04+R01

225kV LIGNE ABOBO 1

ABB

125VDC Distributuion Battery A 125VDC Distributuion Battery B

BAY CONTROL RELAY REC316*4

1

ABBABB Network Partner REL316*4 2 43 5 67 8 9 1211 13 1415 16 10

LOCAL CONTROL

METERING

LINE PROTECTION RELAY REL316*4

1

ABBABB Network Partner REL316*4 2 43 5 67 8 9 1211 13 1415 16 10

BUSBAR PROTECTION REB500

ABB

=D04 ABOBO 1

-Q2 SEL -Q1 SEL -Q0 SEL =W1 =W2 FERMER OUVRIR EXE ESC LAMPE TESTE DISTANCE LOC ABB

?

(29)

INTELLIGENT SA: FEATURES AND BENEFITS

Features

Bus (serial) communication

to primary equipment

Benefits

Further reduction in yard

cabling and installation costs

More information from primary

equipment

Operation enhancements

Reducing operation and

maintenance costs

Intelligent primary equipment

Sampling and signal processing

locally in primary equipment

Less primary equipment costs

Less project execution time

(30)

SUBSTATION

AUTOMATION

SYSTEM

(Stage-5 Development)

PROCESS LEVEL INTELLIGENT SUBSTATION

AUTOMATION WITH

GSM / CDMA NETWORK

PREPARED BY

GOPALA KRISHNA PALEPU

ADE/400KV/ VS/HYD

[email protected],

Mobile:9440336984

(31)

SUBSTATION AUTOMATION SYSTEM (STAGE-5)

1. This system is adopted for New Substations, at the time of tendering.

2. This is Distributed IEDs for each Switch Yard Equipment for Operation and Maintenance. This is

Called Process Bus Automation.

3. Non Conventional Instrument Transformers for Voltage and Current Measurement .

4. In this Distributed Control Rooms / Bay Kiosks / Portable relay Rooms are not required.

5. One complete Panel for one Bay. All control, Protection IEDs TVM/EM are available.

6. No Physical wiring from Switch Yard to Bay to Control. Total GSM/CDMA connection and IEC61850

Communication.

7. But Centralised Auxiliary System and Physical Cabling to all Bay switch yard equipment and relays

and other accessory systems.

8. Switch yard is fixing with no of Digital Cameras and focusing the major equipment to View the yard

and this is having a facility to Move in slow motion, around the bay to cover all the Major

equipments. This also put in Network to Monitor from remote/ Local.

9. The Numerical IEDs , Energy Meters, MFM and Digital Cameras are connected in Network in

Ethernet Switch and to Station Control System and connected through Gateway to Remote Control

Center and ALDC / SLDC / RLDC / NLDC.

10. The Operator, those who are sitting at Remote control Center having a System and he can Monitor

the substation and take a decision for any thing.

11. This is Stage-5 Substation Control System called Process Bus Substation Automation System.

12. Civil Engineering Cost in the yard reduces Drastically.

13. The Main Control Room Having only Network system with Printer and Aux System Monitoring.

14. But still Auxiliary system Location is Centralised, but Not Distributed. This concept is not changing.

15. Redundant, alternative communication channels are required with GSM / CDMA.

(32)

INTELLIGENT GSM/CDMA SA ARCHITECTURE

TO RCC/ALDC/SLDC

ABB Network Partner AG

C

E

COM581

PI

S

A

PI

S

A

PI

S

A

B

PI

S

A

-Q1

-Q2

-Q51

-Q0

-T1

-Q9

-Q8

Process

L

evel

Bay

L

evel

Station Level

?

LOCAL REMOTE SET OPERATION M M M =D04+R01 225kV LIGNE ABOBO 1

ABB

1

ABB ABB Network Partner

REL316*4 2 435678 9 121113141516 10

1

ABB ABB Network Partner REL316*4

2

435678

9

121113141516

10

BUSBAR PROTECTION REB500 ABB ABB Network Partner

REB500

DISTANCE

LOC

ABB POWER MONITORING UNIT

ABB =D04 ABOBO 1 -Q2SEL -Q1SEL -Q0SEL =W1 =W2 FERMER OUVRIR EXE ESC LAMPETESTE

?

EM

GSM

CDMA

GSM

CDMA

GSM

CDMA

GSM

CDMA

GSM

CDMA

(33)

IMPLEMENTATION OF CDMA / GSM INTELLIGENT SAS

t

i i t l

Intelligent Primary Equipment

d gi tal

di gi t al

NCC / RCC

MicroSCADA

ABB

Communication

Converter

COM 581

-Q1

-Q0

-Q8

Feeder Marshalling

-Q9

-Q2

PISA

A

PISA

B

PISA

A

-Q1

-Q2

-Q51

-Q0

-T1

-Q9

-Q8

ABB

125VDC Distributuion Battery A 125VDC Distributuion Battery B

BAY CONTROL RELAY REC316*4

1

2 43 5678 9 1211 13141516 10

LOCAL CONTROL METERING

LINE PROTECTION RELAY REL316*4

1

6. SYSTEM CONFIGUARATION SCREEN.

7. TIME SYNCHRONISATION

8. MONITORING OF CIRCUIT BREAKER.

9. MONITORING OF TRANSFORMER.

10. MONITORING OF CTs, PTs, & CVTs.

11. MONITORING OF RELAYS, ENERGY METERS & PANEL METERS.

12. CONFIGUARATION OF RELAYS

13. DISTURBANCE RECORD VIEW.

14. MONITORING OF SWITCH YARD SURVELLIANCE SYSTEM.

15. MONITORING OF NETWORK

(37)

UTILISATION OF SUBSTATION AUTOMATION

6. SECURITY

A.LIVE CAMERA

B.SURVELLIANCE SYSTEM

C. ENTRY LOG

7. INFORMATION TECH

A. Web Browser View

B. Commissioning Via Web

View

C. Advanced IT Tech

D. Messages

E. Notes

5. ENGINNERING

A. VOLTAGE CONTROL

B. FREQUENCY CONTROL

C. LOAD CONTROL

D. VAR CONTROL

E. GRID CONTROL

F. POWER SYSTEM

ANALYSIS (LOAD FLOW)

G. HARMONIC ANALYSIS

H. SYSTEM STABILITY

I. ABT ANALYSIS

J. GENERATION CONTROL

4. COMMUNICATIONS

A. Analog PLCC

B. Digital PLCC

C. FIBRE OPTIC

D. DIGITAL MICROWAVE

E. VSAT

F. DIDICATED

COMMUNICATION

G. MUX

H. CHANNEL AIDED

PROTECTION

I. DATA TRANSMISSION

3. OPERATIONS:

A. STATION DIAGRAM

B. ALARMS

C. SOE / ER

D. METERING VALUES

E. ICT/ EQUIP PARAMETERS

F. HISTORY

G. SOE

H. DISTURABANCE REPORT

& ANALYSIS.

2. CONTROL&PROTECTION

A. CONTROL (BCU)

B. METERING (BCU)

C. PROTECTIONS (BPU)

D. PROTECTION DIAGRAMS

E. CONFIGUARATION

F. DISTURBANCE

RECORDER

G. ENERY METERS

H. ANALYSIS OF FAULT

I. GPS

J. RTU

1. MAINTANENCE

A. TRANSFORMERS

B. BREAKERS

C. CTs

D. PTs &CVTs

E. LAs

F. ISOLATORS

(38)

MONITORING

OF

SUBSTATION

IN

SMS/SCS/SA

PREPARED BY

GOPALA KRISHNA PALEPU

ADE/MRT(PROTECTION)

PREPARED BY

GOPALA KRISHNA PALEPU

ADE/400KV/ VS/HYD

[email protected],

Mobile:9440336984

(39)

Advanced analysis

tools

Alarm Classes

GPS

Universal Time

synchronization

User friendly

visualization

# Of trips

Sequence of Events

Automatic printing

Summary report

CONCISE / FAST

Distance to Fault

IED Parameter

C

E

Mo 12. 11. 96 GMT 17:02.43.305

Ayer Rajah & Labrador Feeder One

Bay

C

E

R

F

I

O

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

ABB Network Partner AG

REL 316*4

C

E

(40)

Smart Screen “Wizards”

• One Line Diagrams

• Event Logger

• IED Faceplate

• IED Tabular Values

• Annunciator Panel

• Alarm List with Sorting Feature

• Trending

(41)

Substation Level Supervision

• Single line diagram

– U, I

=>”fast”

– P, Q, E

=> “slow”

• Overview pictures

– P, Q,

=> “slow”

• Customised measurements

– P,Q, E

– Summation

– Minimum / maximum

– Average values

– Lists

– Bar charts

(42)

(43)

SUBSTATION DISPLAY (400KV SIDE)

A

KV

MW

MVAR

A

KV

MW

MVAR

A

KV

MW

MVAR

A

KV

MW

MVAR

A

KV

MW

MVAR

A

KV

MW

MVAR

A

KV

MW

MVAR

A

KV

MW

MVAR

A

KV

MW

MVAR

TAP

(44)

SUBSTATION DISPLAY (220KV SIDE)

A

KV

MW

MVAR

TAP

A

KV

MW

MVAR

TAP

A

KV

MW

MVAR

TAP

A

KV

MW

MVAR

F1

F2

A

KV

MW

MVAR

A

KV

MW

MVAR

F3

F4

A

KV

MW

MVAR

(45)

SUBSTATION DISPLAY (220KV SIDE)

A

KV

MW

MVAR

TAP

A

KV

MW

MVAR

TAP

A

KV

MW

MVAR

TAP

A

KV

MW

MVAR

A

KV

MW

MVAR

A

KV

MW

MVAR

A

KV

MW

(52)

Recording of Trends and Alarm Generation

Upper Alarm (A)

hysteresis

Upper warning (W)

Lower warning

Lower alarm

(53)

(54)

ABB Diagnostic: Fault Recording and Evaluation

(55)

(56)

(57)

(58)

(59)

(60)

(61)

(62)

(63)

SUBSTATION AUTOMATION

Base System

Service

Modem

Network Partner SSLTA 88SRS485MSRS485MSREDU/M RS232RS485RS485 SERVICE 1MRSC600291MRSC600281MRSC600281MRSC600281MRSC600281MRSC600281MRSC60028

Rugged Com/Equivalent Ethernet Switches forming ‘Redundant Managed switched Ethernet LAN on fiber optic medium Interbay bus on IEC61850

Communication Gate way with hot standby for RCC and SLDC’ For Control and Protection Relays.

Network Partner SSLTA 88SRS485MSRS485MSREDU/M RS232SERVICERS485RS485 1MRSC600291MRSC600281MRSC600281MRSC600281MRSC600281MRSC600281MRSC60028

Alarm

Unit

Alarm

Unit

Ethernet (TCP/IP)

Printer Server

Alarm/Event

Line Printer

Auxil

ia

ry

Alarm

Ann

unci

ati

o

n

Base System

DM Printer

For 15 Min

Metering &

Trends

Hardcopy

Printer +

MFD

POWER V1 OVP LOCK ACQR SATELLITE CONTROLLED CLOCK

GPS 166 NORMAL OPERATION WED 11.12.1996 MEZ 11.42.25 SV 24 > SYN MENUCLR

ACKNEXT INC

MEINBERG

GPS

C

E

ABB Network Partner AG REL531

910 11 12 13 14 15 16 9 10 11 12 13 14 15 16 910 11 12 13 14 15 16 9 10 11 12 13 14 15 16 9 10 11 12 13 14 15 16 910 11 12 13 14 15 16

RCC LDC

COMMUNICATION

GATEWAY TO

RCC & ALDC

Engineering & DR

work Station

LAPTOP

OTH

AVR

HYD

RAN

EM

DIGITAL

PLCC/

OLTE

SYSTEM

CARR

PROT

SYSTEM

CARR

PROT

SYSTEM

CARR

PROT

SYSTEM

CARR

PROT

SYSTEM

CARR

PROT

SYSTEM

CARR

PROT

SYSTEM

2 Ports for RCC &

2 Ports for ALDC/SLDC

DIGITAL

PLCC/

OLTE

SYSTEM

DIGITAL

PLCC/

OLTE

SYSTEM

OTH

AVR

HYD

RAN

OTH

AVR

HYD

RAN

(64)

CONTROL & RELAY

PANELS IN

CONVENTIONAL

SYSTEM

PREPARED BY

GOPALA KRISHNA PALEPU

ADE/MRT(PROTECTION)

PREPARED BY

GOPALA KRISHNA PALEPU

ADE/400KV/ VS/HYD

[email protected],

Mobile:9440336984

(65)

(66)

79 + 25

(AUTO RECLOSURE +

CHECK SYNC RELAY)

50 Z

(LBB / BFR)

4RLA

CB TROUBLE ALARAM

AND TRIP RELAYS

TSR

TC-1

TSR

TC-1I

DC

I & II

86 GR -A

1-PH TRIP

RELAYS -6

FOR 21M1

86 GR -B

1-PH TRIP

RELAYS -6

FOR 21M2

BREAKER

MULTIPLICA

TION RELAY

UNDER

VOLTAGE

RELAY

D/T CH-1

RECEIVE

RELAYS

D/T CH-2

RECEIVE

RELAYS

400KV LINE CB RELAY & PROTN PANEL

79 + 25

(AUTO RECLOSURE +

CHECK SYNC RELAY)

50 Z

(LBB / BFR)

4RTB

CB TROUBLE ALARAM

AND TRIP RELAYS

TSR

TC-1

TSR

TC-1I

DC

I & II

86 GR -A

1-PH TRIP

RELAYS -6

FOR 21M1

86 GR -B

1-PH TRIP

RELAYS -6

FOR 21M2

BREAKER

MULTIPLICA

TION RELAY

D/T CH-1

RECEIVE

RELAYS

D/T CH-2

RECEIVE

RELAYS

21 MAIN 1

21 MAIN 2

DC

-1

DC

-1I

4RLB

59 L1

O/V STG-1

59 L2

O/V STG-1i

87 LOW

TEED-2

21 MAIN 1

AUX RELYS

21 MAIN 1i

AUX RELYS

87 HIGH

TEED-1

(67)

79 + 25

(AUTO RECLOSURE +

CHECK SYNC RELAY)

50 Z

(LBB / BFR)

4RLA

CB TROUBLE ALARAM

AND TRIP RELAYS

TSR

TC-1

TSR

TC-1I

DC

I & II

86 GR -A

1-PH TRIP

RELAYS -6

FOR 21M1

86 GR -B

1-PH TRIP

RELAYS -6

FOR 21M2

BREAKER

MULTIPLIC

ATION

RELAY

UNDER

VOLTAGE

RELAY

D/T CH-1

RECEIVE

RELAYS

D/T CH-2

RECEIVE

RELAYS

400KV LINE + R CB RELAY & PROTN PANEL

79 + 25

(AUTO RECLOSURE +

CHECK SYNC RELAY)

50 Z

(LBB / BFR)

4RTB

CB TROUBLE ALARAM

AND TRIP RELAYS

TSR

TC-1

TSR

TC-1I

DC

I & II

86 GR -A

1-PH TRIP

RELAYS -6

FOR 21M1

86 GR -B

1-PH TRIP

RELAYS -6

FOR 21M2

BREAKER

MULTIPLICA

TION RELAY

D/T CH-1

RECEIVE

RELAYS

D/T CH-2

RECEIVE

RELAYS

21 MAIN 1

21 MAIN 2

DC

-1

DC

-1I

4RLC

59 L1

O/V STG-1

59 L2

O/V STG-1i

87 LOW

TEED-2

21 MAIN 1

AUX RELYS

21 MAIN 1i

AUX RELYS

87 HIGH

TEED-1

87 MAIN

HIGH IMP

21 IMP

DISTANCE

DC

-1

DC

-1I

4RLRB

75 A

75 B

75 L

64 REF

HIGH SPEED

AUX TRIP

RELAYS

(68)

400KV ICT HV + IV CB RELAY & PROTN PANEL

50 Z

(LBB / BFR)

4RTRA

CB TROUBLE ALARAM

AND TRIP RELAYS

TSR

TC-1

TSR

TC-1I

DC

I & II

86 GR -A

86 GR -B

BREAKER

MULTIPLICA

TION RELAY

INTER TRIP

RECEIVE

RELAYS

INTER TRIP

RECEIVE

RELAYS

87 MAIN 1

LOW IMP

87 MAIN 2

HIGH IMP

DC

-1

DC

-1I

4RTRB

87 HIGH

TEED-1

87 LOW

TEED-2

75 A

75 B

75 L

75 A

75 B

67 HV

67 IV

99T

HV O/F

99T

IV O/F

ICT / ATF TROUBLES

ALARAM & TRIP

FLAG RELAYS

AUX RLYS

FOR HV

AUX RLYS

FOR IV

HIGH SPEED

AUX TRIP

RELAYS

50 Z

(LBB / BFR)

4RTRC

CB TROUBLE ALARAM

AND TRIP RELAYS

TSR

TC-1

TSR

TC-1I

DC

I & II

86 GR -A

86 GR -B

BREAKER

MULTIPLICA

TION RELAY

AUX RLYS

INTER TRIP

RECEIVE

AUX RLYS

INTERTRIP

RECEIVE

(69)

400KV BUS REACTOR CB RELAY & PROTN PANEL

79 + 25

(AUTO RECLOSURE +

CHECK SYNC RELAY)

50 Z

(LBB / BFR)

4RTB

CB TROUBLE ALARAM

AND TRIP RELAYS

TSR

TC-1

TSR

TC-1I

DC

I & II

86 GR -A

1-PH TRIP

RELAYS -6

FOR 21M1

86 GR -B

1-PH TRIP

RELAYS -6

FOR 21M2

BREAKER

MULTIPLICA

TION RELAY

D/T CH-1

RECEIVE

RELAYS

D/T CH-2

RECEIVE

RELAYS

87 MAIN

HIGH IMP

21 IMP

DISTANCE

DC

-1

DC

-1I

4RBRB

75 A

75 B

64 REF

HIGH SPEED

AUX TRIP

RELAYS

87 HIGH

TEED-1

87 LOW

TEED-2

50 Z

(LBB / BFR)

4RBRA

CB TROUBLE ALARAM

AND TRIP RELAYS

TSR

TC-1

TSR

TC-1I

DC

I & II

86 GR -A

86 GR -B

BREAKER

MULTIPLICA

TION RELAY

(70)

400KV BUSBAR PROTECTION & COMMON CONTROL PANEL

(71)

CONTROL & RELAY

PANELS IN

SUBSTATION

AUTOMATION

SYSTEM

PREPARED BY

GOPALA KRISHNA PALEPU

ADE/MRT(PROTECTION)

PREPARED BY

GOPALA KRISHNA PALEPU

ADE/400KV/ VS/HYD

[email protected],

Mobile:9440336984

(72)

400KV & 220KV BUSBAR & COMMON CONTROL PANEL

BCU1

BCU2

BUSBAR

CENTRAL UNIT

4RBB

DC

-1

DC

-2

89BB1

_AE

C

M

R

89BB2

_AE

C

M

R

Bus

Bar

Aux

relays

BCU3

BUSBAR

CENTRAL UNIT

2 RBB

DC

-1

DC

-2

BCU1

BCU2

89BB1

_AE

C

M

R

89BB2

_AE

C

M

R

Bus

Bar

Aux

relays

(73)

400KV LINE + REACTOR CB RELAY & PROTN PANEL

BAY1 BCU

4RLA

A/R+SC

79+25

LBB/ BU

50Z

CB

TROUBLES

& ALARMS

TRIP COIL

1 & 2

HEALTHY

LEDS

86 GR-A

186 R1,Y1,B1

R2,Y2,B2

DC-1

86 GR-B

286 R1,Y1,B1

R2,Y2,B2

DC-2

CB PB

96 50Z

4RLB

21L1

21L2

59-1&2

D/T-1

Receive

Relays

D/T-2

Receive

Relays

BAY2 BCU

4RTB2

A/R+SC

79+25

LBB/ BU

50Z

CB

TROUBLES

& ALARMS

TRIP COIL

1 & 2

HEALTHY

LEDS

86 GR-A

186 R1,Y1,B1

R2,Y2,B2

DC-1

86 GR-B

286 R1,Y1,B1

R2,Y2,B2

DC-2

CB PB

50 ZT

4RLRC1/RBR3

87R

64R

75A,B,L

Reactor Trouble

Alarms & Trips

21R

(74)

400KV ICT CB RELAY & PROTN PANEL

MFM

BAY3 BCU

4RTRA3

LBB/ BU

50Z

CB

TROUBLES

& ALARMS

TRIP COIL

1 & 2

HEALTHY

LEDS

86 GR-A

DC-1

86 GR-B

DC-2

CB PB

Inter

Trip

Relays

96/

50Z

4RTRB3

87T1

87T2

75A,B,L

_75A,B

Transformer Trouble

Alarms & Trips

67HV

67IV

99HV

99IV

MFM

LV BAY BCU

4RTRC3

LBB/ BU

50Z

CB

TROUBLES

& ALARMS

TRIP COIL

1 & 2

HEALTHY

LEDS

86 GR-A

DC-1

86 GR-B

DC-2

CB PB

Inter

Trip

Relays

96/

50Z

BAY2 BCU

4RTB2

A/R+SC

79+25

LBB/ BU

50Z

CB

TROUBLES

& ALARMS

TRIP COIL

1 & 2

HEALTHY

LEDS

86 GR-A

186 R1,Y1,B1

R2,Y2,B2

DC-1

86 GR-B

286 R1,Y1,B1

R2,Y2,B2

DC-2

CB PB

50 ZT

(75)

220KV FEEDER CB RELAY & PROTN PANEL

MFM

BAY1 BCU

2RLA1

A/R+SC

79+25

LBB/ BU

50Z

CB

TROUBLES

& ALARMS

TRIP COIL

1 & 2

HEALTHY

LEDS

86 GR-A

186 R1,Y1,B1

R2,Y2,B2

DC-1

86 GR-B

286 R1,Y1,B1

R2,Y2,B2

DC-2

CB PB

TTS

96 /

50Z

2RLB1

21L1

21L2

D/T-1

Receive

Relays

D/T-2

Receive

Relays

75A

75B

(76)

220KV BC, TBC & BS CB RELAY & PROTN PANELS

BC BCU

2RBC

LBB/ BU

50Z

CB

TROUBLES

& ALARMS

TRIP COIL

1 & 2

HEALTHY

LEDS

86 GR-A

DC-1

86 GR-B

DC-2

CB PB

LBB/ BU

50Z

50/51

A,B

C,N

96 50Z

TBC BCU

2RTBC

LBB/ BU

50Z

CB

TROUBLES

& ALARMS

TRIP COIL

1 & 2

HEALTHY

LEDS

86 GR-A

186 R1,Y1,B1

R2,Y2,B2

DC-1

86 GR-B

286 R1,Y1,B1

R2,Y2,B2

DC-2

CB PB

96 50Z

A/R+SC

79+25

BS BCU

2RBC

LBB/ BU

50Z

CB

TROUBLES

& ALARMS

TRIP COIL

1 & 2

HEALTHY

LEDS

86 GR-A

DC-1

86 GR-B

DC-2

CB PB

LBB/ BU

50Z

50/51

A,B

C,N

96 50Z

Substation Automation

SUBSTATION AUTOMATION

(FROM CONVENTIONAL SUBSTATION TO GSM/CDMA AUTOMATION SYSTEM)

PREPARED BY

GOPALA KRISHNA PALEPU

ADE/400KV/ VS/HYD

[email protected],

Mobile:9440336984



From substation control and protection to

Fibre optics based Substation.



Fibre optics based Substation to GSM /CDMA

based Substation Automation.



From modern to intelligent Substation

Automation



System Architectures



Functional Structures



Application examples

¾

IT based solution for protection and control offer cost

effective measures to counteract large area system

disturbances.

¾

Effective fault location is mandatory for faster finding

and fixing of problems.

¾

Integrated numerical protection & control allows

automated power restoration and load shedding.

¾

On-line condition monitoring reduces maintenance

costs and enables.

¾

Substation Automation offers a cost effective

infrastructure for implementing on-line condition

monitoring of assets.

¾

Voltage instability prediction is a new approach for

early indication voltage collapses and enables to

work plants and systems harder.

¾

Integrated asset management improves overall

General Principles of Substation Automation

The general principles of the substation operation have

not changed, since their developing days. Therefore the

control and protection tasks remain the same.

The objective of modern substation automation (SA) is to

solve these tasks in a more efficient and economical way

by using state of the art information technologies (IT) and

to provide more functionality to work plant and systems

harder.

CONVENTIONAL

SUBSTATION

PRACTICES

PREPARED BY

GOPALA KRISHNA PALEPU

ADE/400KV/ VS/HYD

[email protected],

Mobile:9440336984

CONVENTIONAL SUBSTATION

1.

Very Wide Cabling. i.e. from equipment to BMB/CTMB/CVT MB and from BMB/CTMB/CVT MB to

Control Room Dedicated Device.

2.

For each function Dedicated Device.

I.

Bay Control – Control Panels for the Bay

Circuit Breaker Control & Indication.

Isolator Control & Indication.

Earth Switch Indication.

DC & AC Healthy Indication and Testing.

Annunciation facia for Troubles.

Panel Meters & Energy Meter.

II.

Bay Protection – Relay & Protection Panels - Protective Relays of Concerned bay

Circuit Breaker Relay Panel (A/R, LBB, TSR, CB Troubles, Master Trip Relays etc).