CHP050 Substation Automation Systems - Day 2 - Bay Control Solutions Rev.1

© ABB Group May 29, 2012 | Slide 1

Global sales program Bay control solutions

Stefan Meier, Substation Automation Systems, 2012-05-29


Content

Introduction

Control concepts and functions

Control IED portfolio

Positioning of control devices

RTU control application examples


Introduction Function allocation

Sta

tio

n

level

Bay l

evel

Pro

cess

level

Functional allocation

Station automation

Monitoring

Fault evaluation

Event & alarm viewing

and acknowledgement

Remote communication for

telecontrol & supervision

Protection

Control

Monitoring

Interlocking

Data acquisition

GIS or AIS switchgear

Instrument transformers

Power transformers

Surge arresters

Non-conventional transf.


Introduction Technology evolution

RTU RTU RTU

RTU RTU RTU

parallel,hardwired

cabling

parallel,hardwired

cabling

parallel,hardwired

cabling

Interbay Bus Interbay Bus

Process Bus

Station Bus Station Bus


What is bay control?

What is bay control

Safe operation of a substation switching device to bring the

substation from a current state to the desired end-state.

Relevant considerations

Status of the substation (persisting alarm conditions, on-

going maintenance activities)

Status and capabilities of the switching equipment

(position indications, CB operating capabilities)

Interlocking conditions to assure personal safety and avoid

damage to the equipment

Control priorities and authority of different operating places

Coordination with protection devices (persisting protection

trips)

Supervision of the switchgear and notification of the users (runtime

supervision, trip-coil supervision, CB monitoring, SF6 supervision,

…)


Control of substations From local to remote control


Marshalling kiosk

Signal marshalling

and local control

per feeder

Drive box

Local control of one

breaker /

disconnector

directly on the

motor drive

Relay house

Control panel in

Relay house in the

switchyard, eg one

house per diameter

Protection room

Control panel may

also be located in a

central protection

room

Network control

centre

Remote control of

several substations

from national or

regional control centres

Station automation

system

Remote control of the

entire substation from

the SAS

From local to remote,

with decaying priority

Control of substations Control locations in a AIS substation (1 ½ breaker, transmission level)


1 per

CB

1 per diameter

Drive box


breaker /

disconnector

directly on the

motor drive

Marshalling kiosk

Signal marshalling

and local control

per feeder

Relay house

Protection and

control of one feeder

in Relay house in the

switchyard

Station automation

system



the SAS

1 per substation

1 per

CB

1 per

CB

Control of substations Control locations in a GIS substation (1 ½ breaker, transmission level)


Drive box


breaker /

disconnector

directly on the

motor drive

Station automation

system



the SAS

1 per substation

Protection room

Control panel may

also be located in a

central protection

room

Local control

Control panel next

to or integrated in

the GIS switchgear

1 per substation

1 per

CB

1 per

CB

1 per

CB


Control concepts and functions


Control concepts Content

Control concepts

Conventional and modern control

Basic control philosophy


Control concepts Introduction

Remote control Local integrated control Local control

Switchgear type

GIS/AIS GIS/AIS GIS

Typical application

Sub-transmission/

transmission

Distribution Transmission

Layout

Control cubicle in relay room,

AIS with marshalling cubicle

IED installed in switchgear panel LCC attached to or installed next

to GIS

Functions of control

IED

Control, sometimes with backup

or main2 protection

Protection and control in one IED Control, sometimes with backup

or main2 protection

ABB IEDs

REC650, REC670 REF615, REF630 REC670


Control concepts Conventional and modern control

Conventional

Bay control mimic

Seamless integration into Substation

Automation Systems through IEC61850

for remote control and supervision

Allows integrated functionalities like

synchrocheck, autoreclosure and backup

protection

Future prove, as they allow integration of

non-conventional current and voltage

transformers

Modern

Bay control IED

Hardwired connection to separate remote

control panel or RTU system

Dedicated equipment required for

additional functionality

Simple but limited technology, relying on

discrete electromechanical equipment


Control concepts Conventional and modern control

Conventional LCC

Normally used if integration into SA

system is not in scope of LCC supplier

The Bay Controller is located in a

separate remote control cubicle (RCC)

High overall space requirement for

LCC and RCC

-

QA1

-

QC2

-QC1

-

QB61

-

QB62

-T2

-T1

-

QA1-

QC2

-QC1

-

QB6

-

QB2

-T1

BBII

-

QB9

-QC9-

QA1

-

QC2

-

QC1

-

QB1

-

QB6

-T1

BBI

-

QB9

-

QC9

A

B B

A

B

A

B B

ABBABBABB

ABB ABB ABBABB ABB

ABB

Local

Control

Cubicle

Protection

Cubicle

IEC61850

Remote

Control

Cubicle

Modern LCC (combination of LCC and

RCC)

Direct integration of LCC into station

automation system

Less overall space for panels required

Fewer inter-panel cabling

Lower overall cost


Control concepts Basic SA control philosophy

-Q1 -Q0 -Q8 -Q9

-Q2

DCB

Station automation solution (SAS)

Bay l

ev

el

Gateway

Pro

cess lev

el

Local control

Emergency control

Sta

tio

n lev

el

Station level

Remote control via station computer or

independent gateway

Station control via SAS

Bay level

Local control via IED display

Emergency control (independent from IED)

via conventional mimic or control buttons

Process level

Emergency control function in drive control

boxes depending type and supplier

(e.g. crank handle or push buttons)

DCB

Co

ntr

ol

pri

ori

ty

Hig

h

Lo

w

DCB DCB DCB


Bay control functions Content

Function overview

Remote control interface

Protection Interface

Local control facilities

SA control philosophy

Local alarm indication

Marshaling

Drive Control

Supervision function

Interlocking


Bay control functions Function overview

Local Control Cubicle

Drive

control

Marshaling

Emergency

control

Interface to

remote

Interface to

remote

Control and

HMI Protection

Drive

control

The various functions of a

control solution can be

allocated to different panels

and devices, depending on

the station layout and

requirements


Remote control interface For conventional solutions

Parallel interface for remote control

via RTU or bay controller (placed in

a separate cubicle)

Parallel interface in conventional

solutions includes:

Position indication of each

primary equipment

On / Off command for each

primary equipment

Alarms as on local annunciator

Control authority status /

Interlocking override status

Drive auxiliary contacts from

primary equipment

(1:1 wired to terminals, free usable

for customer)

Hardwired interface for station

interlocking

Drive

Control

Marshaling

Emergency

Control

Interface to

Remote

Primary Equipment Interface

Protection

Interface

Bay

Control

Drive

Control

RTU or

bay control IED

HW station interlocking


Remote Control Interface For modern solutions

IEC61850 communication interface

to station bus

Communication to station

automation system (SAS)

Reporting of events, alarm,

status information,

measurements

Control commands from SAS

Configuration of control IED

Reading of disturbance

records, IED maintenance

information

Bay to bay communication

(GOOSE)

Double operation blocking

Interlocking

Drive

Control

Marshaling

Emergency

Control

Interface to

Remote


Protection

Interface

Bay

Control

Drive

Control

Station bus (SAS, interlocking)


Drive

Control

Marshaling

Emergency

Control

Interface to

Remote


Protection

Interface

Bay

Control

Drive

Control

Protection Interface

Protection interface for all status information and

control circuits who are required for the

protection solution

CT / VT circuits

Trip I & II circuits

Trip and Close circuit supervision interface

Autoreclosure command

Manual close, VT MCB status, CB position

status

OCO Ready, CB Ready, CB and BB

disconnector position for Autoreclosure and

Synchrocheck

Manual close, CB and BB disconnector

position for BBP / BFP protection

Protection status information for alarm

indication in the LCC

All drive position indications for protection

come from primary apparatus auxiliary

contacts

To protection


Bay control functions Local control facilities

IED HMI

Visualization of single line, measurements, alarms,

events, parameters

Local control of the feeder with function buttons

Mimic with direct control

Control object status indication with LED’s

Display of measurements

Operation authority (Local, Remote, Off)

Local control via control buttons (select before

operate or two-hand-operation)

Independent of IED

CB emergency control

Direct control buttons with authority key switch

Independent of IED Circuit Breaker

Close Command

Circuit Breaker

Open Command

Circuit Breaker

Pump Reset

Authority Switch


Bay control functions Select before operate concept

+

-Q1

-Q0

-Q8

-Q9

-Q2

1 2

Selection

At selection of an object, control

conditions is verified by the IED

Double operation blocking is sent out

independent output is executed

(minus circuit)

3 Execution

Execution command is verified in the

IED

independent output is executed (plus

circuit), the breaker/ disconnector

operates

The select before operate concept

guaranties a maximum of operation

safety!

1

2

3


Bay control functions Select before operate concept – enhanced security

ABB’s 650 and 670 series

IEDs support SBO with

enhanced security

Normal security:

only the command is

evaluated and the

resulting position is not

supervised.

Enhanced security

command sequence is

supervised in three

steps, the selection,

command evaluation

and the supervision of

position.

Bay control functions Synchronizing and synchrocheck

Synchrocheck, energizing check, and

synchronizing function (SESRSYN) checks

that the voltages on both sides of the circuit

breaker are in synchronism


RSYN

RSYN, energizing

RSYN, synchrocheck

RSYN, synchronizing

Energizing check releases CB closing if one

side of the CB is de-energized

Synchrocheck releases CB closing if delta

values across the CB are within defined limits

Voltage level difference.

Frequency difference (slip)

Phase angle difference.

Synchronizing functionality is used if

frequency difference across the CB is bigger

than allowed by the synchrocheck function

(and lower than max limit)

Close command is issued at optimum

time to close when phase difference is

within limits


Bay control functions Local alarm indication

Fault indication with 16 LED’s

Annunciator with push buttons for..

Lamp test

LED’s acknowledgement

Horn acknowledgement

Fault indication of …

Protection information (tripped,

disturbed)

Circuit breaker information (spring

blocked, SF6 blocked, TCS failed,

pole discrepancy)

SF6 gas (refill, urgent disconnect)

MCB status (AC, DC, VT)

Crank handle in use Modern solution

Conventional solution


Drive

Control

Marshaling

Emergency

Control

Interface to

Remote


Protection

Interface

Bay

Control

Drive

Control

Bay control functions Marshaling

Marshaling of:

DC supply

LCC internal

Switchgear drives

AC supply

LCC light

LCC heater

drive heater

CT / VT circuits (VTs are

protected with MCBs)

SF6 gas compartment status

Grouping of SF6 gas refill

Grouping of SF6 urgent

disconnect


Drive

Control

Marshaling

Emergency

Control

Interface to

Remote


Protection

Interface

Bay

Control

Drive

Control

Drive control Overview

Drive control includes …

Circuit breaker control and

supervision

Hydraulic pump control and

supervision

Disconnector and earthing

switch control


Drive control Circuit breaker control and supervision

Anti-pumping control

Prevents the repeated undesired closing of a breaker in case

the CB is in open position and open command persists

protect the CB from toggling

Circuit-breaker blocking

Closing and tripping circuits will blocked by low SF6 gas

pressure

If spring-pressure below O-C-O

autoreclosure circuit will be blocked

If spring-pressure below C-O

close operation will be blocked

If spring-pressure below O

trip circuit will be blocked

Pole discrepancy function

Detects a discrepancy in the pole positions of the CB

activation of three phase trip command

Interlocking


Drive control Hydraulic pump control and supervision

Pump start cascading

Simultaneous start of the three pumps, would generate high

peak load on the DC battery

250ms time delay between pump starts

Pump start supervision

If more than 10 unforced pump operations (without CB

operation) occur within 24h, an alarm will be generated

Hydraulic system has to be checked

The Pump Reset button at the mimic will light up continuously

Pump runtime supervision

At each pump start, it is supervised whether the spring is fully

charged after 2 minutes. If not, the PLC will block all pumps

Pumps will be protected from overheating

The Pump Reset button at the mimic will light up continuously

Pump start counter

Circuit breaker operation counters

For HMB

CB operating

mechanisms


Bay control functions Supervision function example – SF6 density

Supervision of SF6 density

in circuit breaker and GIS

2 Binary alarm levels

Refill alarm

Urgent disconnect

Analog (4..20mA)

signals for trending and

enhanced supervision

Often dedicated

systems due to the

high number of

signal inputs (~18

per transmission

GIS feeder)

Sta

nda

rd f

un

ction

Specia

l fu

nction

Binary signals to

control and

protection

4...20 mA


Bay control functions Supervision function example – CB monitoring

Monitoring of CB condition

Typically supervised

values:

Breaker contact travel

time

Operation counter

Accumulated opened

energy

SF6 density

Trip curve for typical 12kV, 16kA CB

Specia

l fu

nction

Bay control functions Interlocking

Blocking:

command block of a switch because of conditions

concerning this switch only.

Examples: gas density, switching energy, defect switch,

defect back indications etc.

Interlocking:

command block of a switch because of other switch

positions in the switch yard

Examples: closed earth switches, moving switches,

busbar transfer etc.




Interlocking blocks the operation of switching devices to:

prevent danger to human life

prevent damage to the switchgear

assure meaningful protection operation

avoid unnecessary operation of switching devices

Bay interlocking (bay-internal switch positions)

Station interlocking (bay-external switch positions):

via hardwired station interlocking bus

via communication bus IEC61850



Basic principles

Disconnectors shall not be opened or closed on-load

Earthing switches shall not be closed onto voltage

CBs shall not be closed when surrounding disconnectors are in intermediate positions

CB opening is only interlocked at a bus-coupler bay, if a busbar transfer is in progress



Safety aspects

All switch positions are transferred as double indications

Single defects (eg, loose wire) do not cause wrong behaviour

Switching releases may be transferred as double indications

Single errors (eg, loose wire) lead to blocking of operation

Consider unknown states

Unknown states need to be verified and failure is in the process or the control system need to be repaired. Otherwise a second failure in the control system may lead to unsafe situations.


Station interocking Hardwired and IEC 61850 GOOSE

Control Control Control

IEC 61850

station bus

Hardwired

station bus

Control Control Control

IEC 61850

station bus

GOOSE GOOSE

Distribution of information

between bays is done

through auxiliary contacts

and parallel wiring

All information is

exchanged through the IEC

61850 station bus network


Station interocking GOOSE example

Disc QB1 and QB2 closed

WA1 not earthed

WA2 not earthed

WA1 and WA2 interconn.

Disc QB1 and QB2 closed

WA1 not earthed

WA2 not earthed

WA1 and WA2 interconn. . . . . .

Station bus

QB1

WA1

WA2

Bay 1 Bay n Bus coupler

WA1 unearthed

WA1 unearthed WA1 and WA2 interconn.

WA1 and WA2 interconnected

in other bay

QB2

QA1

QB9

QB1 QB2

QA1

QB9

QB2 QB1

QA1

QC1 QC2


Station interlocking IEC61850 interbay bus (GOOSE)

IEC 61850-8-1

GOOSE

Generic Object Oriented Substation

Event

Testing without GOOSE simulator is

difficult/ expensive

Extension of existing installation or

stepwise extensions may require

configuration changes in each IED

In case an IED is switched off, the

status information of the affected

feeder are missing (maintenance)

No wiring between panels

No additional I/Os required for

station interlocking information

Additional information can be

transmitted e.g. double operation

interlocking, disturbance recorder

triggering etc.

All signals are continuously

supervised

Advantages Challenges


Station interlocking Hardwired interlocking bus

IEC 61850-8-1

Hardwired Interlocking Bus

More cabling between panels

Additional I/Os required for station

interlocking information

More auxiliary contacts required on

CB/ disconnector/ earth switch

drives

External power supply in all panels

for station interlocking bus (e.g.

from bus coupler)

Simple testing

Easy for future extensions or

stepwise commissioning (no

changes of the IED configuration

required)

Maximum availability because

position information on the

hardwired bus are direct from the

primary equipment and

not via an IED

Advantages Disadvantages


Control IED portfolio


Application, Price,

Functionality,

Performance

REC670

REC650

REF630

REC601/3

REF615

Sub-transmission Transmission Distribution

Control devices Overview

REC601/603 Control in automated distribution networks

Wireless Controllers REC601/603 for automated distribution

network

Local and remote control and monitoring of up to three (3)

objects (REC603)

Disconnector and earting indications with front LEDs

More than one REC601/603 can be connected in a single

location to facilitate the Ethernet enabled control and

monitoring of more disconnectors

Overload protection of actuator motors

Load current measured in the motor circuit

Energy limit based motor overload protection (“software

fuse”)

Always-on two-way communication based on GPRS

Redundant IEC 60870-5-104 connections

High level data security through internal VPN and Firewall

Possibility to act as an IEC 60870-5-101 master (router) for

another communicating sub-device

Built-in battery charger

Heater control to limit effects of ambient temperature variations

Real-time clock for accurate event time-tagging


615 series Control and protection in distribution substations

Control of one circuit-breaker (CB) via the IED’s

human-machine interface (HMI) or a remote control

system

Interlocking schemes

Predefined configurations can be modified in

PCM600 graphical application configuration (ACT)

Designed for IEC 61850

Binary and analog GOOSE messaging

REF615 also supports:

Modbus®

DNP3

IEC 60870-5-103

An optional second Ethernet bus enables the

creation of a self-healing Ethernet ring

Optional three-channel arc protection system


REF615 feeder protection

and control IED

RED615 line differential

protection and control IED

RET615 transformer


REU615 voltage protection

and control IED

REM615 motor protection

and control IED

630 series Control and protection in distribution substations

Control of circuit-breaker and motor operated

disconnectors via the IED’s local HMI or a remote

control system

Dedicated push-buttons for opening

and closing

Configurable single line diagram

Status of primary apparatus

Selected measurement values

Programmable interlocking schemes for bay and

station level interlocking


Binary and analog GOOSE messaging

The IEDs can be ordered with or without product-

specific factory-made application pre-configurations

The configurations can be modified in PCM600

graphical application configuration tool (ACT)

4U and 6U housing with different I/O configurations


REF630 feeder protection

and control IED

RET630 transformer


REM630 motor protection

and control IED

REC650 Control in sub-transmission substations

Apparatus control for up to 8 apparatus with

integrated backup protection

Ready-to-use configured IEDs for 3 network

configurations

The configurations can be modified in PCM600

graphical application configuration tool (ACT)


Binary GOOSE messaging

Safe and dependable reservation method for

apparatus control

Well proven standard interlocking functions

Powerful and extensive HMI functionality eliminates

the need for external mimic boards


REC650 bay control IED

REL650 line distance

protection IED *

RET650 transformer

protection IED *

REQ650 breaker

protection IED *

REG650 generator

protection IED *

* Without control functions

REC670 Control in sub-transmission & transmission substations

Local and remote control of up to 6 bays and 30

apparatus

Extensive function library according to IEC 61850

Extensive analog and binary I/O capability

Completely configurable to the most demanding applications


Binary GOOSE messaging

Select before operate with enhanced security

Well proven standard interlocking functions

Powerful and extensive HMI functionality eliminates

the need for external mimic boards

Integration of non-conventional instrument

transformers using IEC 61850-9-2LE

Control functions are also available in the protection

IEDs


RTU560/RTU211 Control in distribution, sub-transmission & transmission substations

Various communication interfaces

Selectable RS232/RS485 interfaces

Ethernet 10/100 Mbps interface

SDSL modem, GPRS modem, fiber optic, FSK

modems

Wide range of host and client protocols

IEC 61850 as client or server with proxy

functionality

Integrated web server for diagnosis, administration,

archive and HMI

Programmable logic controller (PLC) according to

IEC 61131-3

Rack based solution

Very flexible, compact and space saving solution

Redundant power supply, CPU and host communication options

Cost efficient for medium and larger systems

DIN rail mounted solution

Low space requirements

Cost efficient for low end and small applications © ABB Group May 29, 2012 | Slide 47


Positioning of control devices

Control IED portfolio Content

Overall positioning

Details REC650/REC670 and their positioning


Devices for control Overview


Functions REC670 REC650 REF630 REF615 REC601/603 RTU560 rack

RTU560/211

DIN rail

Transmission

Sub-transmission

Distribution

Secondary distribution

Controllable bays 6 1 1 1 1 “unlimited” “unlimited”

Controllable objects 30 (6CBs) 8 (1CB) 10 (2CBs) 1CB

(indication of 3DS, 1ES)

3 “unlimited” “unlimited”

Max. binary Inputs/outputs 208/961) 50/451) 50/451)2) 18/131) 5000 datapoints 750 datapoints

Max. analog inputs 241) 101) 101)2) 91)

Automatic voltage control

of parallel transformers yes (RET650) (RET630) (RET615)

External or PLC

program

External or PLC

program

Protection Main & backup Backup Main & backup Main & backup external external

Tripping type 1ph & 3ph 3ph 3ph 3ph 3ph

Pre-configurations

IEC 61850 station bus

NCC/DMS communication

GSM/GPRS modem integr

1) The maximum numbers are influencing each other and are mutually exclusive. 2) Numbers are for 6U casing. Less I/Os for 4U casing


Tap changer control Protection IED Control IED

AR, backup protection Protection IED Control IED

Synchrocheck Protection IED Control IED

WebHMI control RTU RTU as IEC 61850 client

Interlocking Hardwired

RTU (and hardwired)

Control IED

Remote control

Hardwired interface

RTU

IEC 61850

Control IED

IEC 61850

Local control

Bay control mimic Bay control mimic Control IED Display

Control concept

Conventional Conventional with RTU Modern with IED

Bay control Overview: Functions and control concepts

Control functions

REC670

RTU

Conventional

LCC


Pro

tectio

n

Syn

c, A

R

U/I

me

as

IEC

61

85

0

GP

RS

--

-- --

--

--

-- --

-- -- -- --

Controllable objects

1 Object (3 indications) 10 Objects (2CB) 8 Objects (1CB) 15 Objects (2CB) 30 Objects (6CB) Voltage level

secondary distribution distribution sub-transmission transmission

Bay control Overview: functions, controllable objects, voltage levels

Functions

REC601/603

RTU

REF615

REF630

REC650

REC670

Control IED portfolio Content

Overall positioning

Details REC650/REC670 and their positioning



REC670 control Pre-configured solutions

REC670 Control Pre-Configured Solutions

Main Functions A30 B30 C30

Physical arrangement Single-breaker

(double/sing. bus) Double breaker 1 ½ Breaker

1Ph high impedance differential protection option option option

Four step phase and residual overcurrent protection option option option

Thermal overload one/two time constants option option option

Breaker failure and under/over power protection option option option

Under/over voltage, under/over df/dt frequency option option option

Auto-reclose option option option

Synchrocheck ● ● ●

Apparatus control for single bay, max 8 apparatuses

(1CB) incl. interlocking ●

Apparatus control for single bay, max 15 apparatuses (2CBs)

incl. interlocking ●

Apparatus control for up to 6 bays, max 30 apparatuses

(6CBs) incl. interlocking ●

Automatic voltage control for tap changer, single/parallel option option option

Tap changer control ● ● ●

Fault locator option option option

=QA1

=QB1 =QB2

=QB9

=QC9

=Q1


REC650 bay control Configured solutions

REC650 Bay Control Configured Solutions

Main Functions A01 A02 A07

Physical arrangement Single breaker

single busbar

Single breaker

double busbar

Bus coupler

double busbar

Interlocking for line bay ● ● ●

Interlocking for transformer bay ● ● ●

Interlocking for bus coupler bay ● ● ●

Interlocking for 1 1/2 breaker diameter ● ● ●

Interlocking for double CB bay ● ● ●

Four step phase and residual overcurrent protection ● ● ●

Thermal overload protection, one time constant ● ● ●

Breaker failure and stub protection ● ● ●

Under/over voltage, under/over df/dt frequency ● ● ●

Auto-reclose and synchrocheck ● ● ●

=QA1

=QB1 =QB2

=QB9

=QC9

=Q1


Bay control Communication comparison

Communication Product Family

Station communication REC670 REC650

SPA communication protocol ●

LON communication protocol ●

IEC 60870-5-103 communication protocol ● ●

Selection between SPA/IEC60870-5-103/DNP for SLM ●

DNP3.0 for TCP/IP and EIA-485 ● TCP/IP

DNP3.0 fault records for TCP/IP and EIA-485

communication protocol ● TCP/IP

DNP3.0 for serial optical communication protocol ●

IEC 61850-8-1 station bus communication ● ●

PRP redundant station bus communication ●

HSR redundant station bus communication

Horizontal communication via GOOSE for interlocking 59 59

GOOSE binary receive 10 4

Process bus communication

IEC 61850-9-2LE ●

Future


Bay control Functionalities

Functionalities Product Family

Main Functions REC670 REC650

1Ph high impedance differential protection ●

Four step phase and residual overcurrent protection ● ●

Thermal overload one/two time constants ● one time constant

Breaker failure protection ● ●

Under/over voltage, under/over/ df/dt frequency ● ●

Auto-reclose and synchrocheck ● ●


(1CB) incl. interlocking ● ●



Apparatus control for up to 6 bays, max 30 apparatuses


Automatic voltage control for tap changer,

single/parallel ●

Tap changer control ●

Fault locator ●

=QA1

=QB1 =QB2

=QB9

=QC9

=Q1


Bay control Positioning

Product REC670 REC650

Segment Transmission Subtransmission

Controllable objects, max 30 8

Controllable bays, max 6 1

Automatic voltage control of parallel

transformers ●

Reservation between bays Basic + Advanced Basic

Tripping type 1Ph and 3Ph 3Ph

Case size 6U ½ 19”, 6U ¾ 19”

6U 1/1 19” 6U ½ 19”

Setting groups 6 4

=QA1

=QB1 =QB2

=QB9

=QC9

=Q1


Tap changer

control

1ph Backup

protection

Breaker failure

protection

Autoreclosure

3ph Backup

protection

Breaker failure

protection

Autoreclosure

CB and trip

circuit Monitoring

Controllable objects

1 6 Controllable bays

8 Objects (1CB) 15 Objects (2CB) 30 Objects (6CB) Controllable objects

REC650 and REC670 bay control IEDs Overview: Functions and controllable objects

Functions

REC670

REC650

REC650 REC650/670 REC670


Multi feeder control

1 ½ breaker

1 IED per diameter

2 breaker arrangement

1 ½ breaker

1 IED per CB

2BB

single breaker

1BB

Casing and I/O

6U ½ 19” 6U ½ 19” 6U ¾ 19” 6U 1/1 19” Casing

50 321) 1121) 2081) Max. binary inputs

45 241) 961) 961) Max. binary outputs

10 12 241) 241) Max. analog inputs

0 0 241) 241) Max. mA inputs

REC650 and REC670 bay control IEDs Overview: Switchgear layout versus I/Os

Switchgear layout

REC650

REC670

1) The maximum numbers are influencing each other and

are mutually exclusive.

REC650 REC650/670 REC670


Multi feeder control

1 ½ breaker

1 IED per diameter

2 breaker arrangement

1 ½ breaker

1 IED per CB

2BB

single breaker

1BB

Primary apparatus

1 drive, 3pole operated 1 drive, 1pole operated 3 drives, 1pole operated CB

3pole position indication 1pole position indication Fast acting ES

3pole position indication 1pole position indication DS/ES

Binary signals Analog signals (mA) Temp., density, …

REC650 and REC670 bay control IEDs Overview: Switchgear layout and primary apparatus

Switchgear layout

Case: 6U ½ 19”

Case: 6U ¾ 19”

Case: 6U 1/1 19”

REC670

REC650

REC650 REC650/670 REC670


RTU control application examples


Diagnosis IEC60870-5-101,

IEC60870-5-104, DNP3, DNP3 over WAN

Control system

Integrated HMI

IEC 61850-8-1

IEC 60870-5-103,

DNP3,

MODBUS

I/Os IEDs

IEDs

PLC

functions

Control level

Station level/ bay level

Communication level

Process

level

RTU application example RTU as Hybrid solution

RTU application example RTU in secondary distribution substations


Covered functions

Remote control of distribution substation from

NCC/DMS

Wide range of communication media (eg,

GPRS modem)

Optional

U/I measurement by integrating transducer

interfaces

Overcurrent detection

Total harmonic distortion (THD)

PLC applications for voltage dip detection

Limitations

-

Suitable for

Remote control of secondary distribution

substations

Medium number of datapoints

RTU application example RTU in distribution substations


WebHMI

IEC 61850

to SAS

or

NCC/DMS Covered functions

Remote control of distribution substation from

NCC/DMS or SAS

Optional

Local control for maintenance through RTU

WebHMI

Integration of IEC 61850 protection IEDs

U/I measurement by integrating transducer

interfaces

Limitations

Synchrocheck has to be performed by

dedicated devices or protection IEDs

Dedicated protection IEDs required

Suitable for

Retrofit of conventional SS

Remote control of simple SS with conventional

protection

RTU application example RTU in sub-transmission and transmission substations


IEC 61850 to RTU or SAS

Local control

panels

Protection

panels

WebHMI

IEC 61850

to SAS

or

NCC

Covered functions

Remote control from NCC

Station control from SAS via IEC 61850, or

Station control from RTU WebHMI

Optional

Integration of IEC 61850 protection IEDs

Limitations

Synchrocheck has to be performed by

dedicated devices or protection IEDs

RTU time stamp accuracy does not meet

usually specified 1ms

Suitable for

Retrofit of conventional SS without changing

conventional control concept

Substation automation and simple control for

small sub-transmission/transmission

substations

Binary

I/O

Analog

inputs


Bay control solutions


Bay control functions Function allocation

ABB transmission GIS Other GIS AIS Remote Control Cubicle Local Control Cubicle Local Control Cubicle

Drive

control

Marshalling

Emergency

control

Interface to

remote

Interface to

remote

Control and

HMI Protection

Drive

control Drive

control

Marshalling

Emergency

control

Interface to

remote

Interface to

remote

Control and

HMI Protection

Drive

control

Drive

control

Marshalling

Emergency

control

Interface to

remote

Interface to

remote

Control and

HMI Protection

Drive

control

Marshalling Cubicle

Allocation of

functions and

equipment,

depending on

the controlled

switchgear


BCS solution overview

BCS 652—local control and

protection cubicle in sub-

transmission substations

BPS 61x/63x—configured feeder

terminals for GIS and AIS in

distribution substations

BCS 651—configured control IED for GIS in sub-transmission substations

BCS 670—remote control

cubicle and marshalling kiosk for

AIS in transmission substations

BCS 690—local control cubicle

for GIS in transmission

substations

BCS 680—remote control

cubicle for GIS and AIS in

transmission substations

Bay control solutions Scope


Control solutions

Marketing material

Base design docs

Detail design

Hardware

Detail design

Software

Test instructions

Templates and part drawings in E3

environment

IED configurations and I/O lists

Block diagrams

Presentations and brochures

Test instructions and reports


Documents

CHP050 Substation Automation Systems - Day 2 - Bay Control Solutions Rev.1