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Copy of Master Thesis Presentation

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Ally Raxa

on 28 January 2014

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Transcript of Copy of Master Thesis Presentation

Vinode Kumar (Group Leader) 10EL106
Ali Raza Memon (Assistant Group Leader) 10EL129
Junaid Kazi 10EL102
Dileep Kumar 10EL87
Tahseen Azeem 10EL127
Fahad Altamash 10EL134

ANALYSIS OF SUBSTATION BY
AUTOMATION

Thesis Objective
How Can we increase the life and reliability of
an existing substation?


Life and reliability of substation can be achieved by
upgrading conventional system in
Substation Automation System

Introduction
Conventional substations are designed using standard design
procedures for the high voltage switchgear in combination
with copper cables for all interfaces between primary and
secondary equipment.



Conventional Substation

Conventional substation has large number of components such as auxiliary relays
Wide copper cables for all interfaces between primary and secondary equipment.
Disadvantages
Installation and Commissioning
Maintenance and Testing:
Expandability
For each function Dedicated Device are required.

A Substation Automation System (SAS) performs Control, Protection, Metering & Monitoring functions using Intelligent Electronic devices (IEDs) which digitally communicate with each other to perform these tasks in a coordinated & efficient way.

These IEDs are interoperable.

A SAS is presently limited to performing tasks within a Substation.

Function within a SAS can be performed by exchanging data/information between the Logical Nodes within the Substation.

Substation Automation System

The main substation automation (SA) function consists of several sub-functions which are appropriately interfaced. These sub-functions are known as Logical Nodes (LN).

The sub functions are of three levels
Process level
Bay level
Station level .

FUNCTIONAL ARCHITECTURE OF SUBSTATION
AUTOMATION SYSTEM


This project aims to automate a conventional
132kV substation using the Substation Automation
System (SAS) using the latest communication protocol
viz. IEC61850 for improving the reliability and efficiency
of the system.


We replace the conventional relays with modern Siemens protection IEDs 6MD66 & 7SD522.

In this project we use IEC 61850 communication
protocol for rapid communication between bay level
and station level.
A protocol is basically a set of rules that must be obeyed for orderly communication between two or more communicating parties.

Communication between 3 levels is called vertical communication and connected by high-speed Ethernet station bus and process bus.

Communication within one level is horizontal communication.



COMMUNICATION PROTOCOLS


DNP3 and IEC 60870-5-104 master/slave based fieldbus communication and can only be implemented till station level and bay level.

IEC 61850 client/server communication fully supports the interoperability among IEDs supplied by different vendors in the substation and can be applied also in process level.
IEC 61850 is basically a Utility Communications Architecture 2.0 (UCA2.0).

It translates all in the information in the real substation into information models in the form of standard naming conventions structures and formats for easy information management.

It standardizes a Substation Configuration description Language (SCL) to describe substation topology, information models, binding to process, communication and data flow, etc.

It provides communication protocols of TCP/IP based SCADA, real time Generic Object Orientated Substation Event (GOOSE).

It defines process bus which is supported by GOOSE and can minimize substation wiring by converting data of CTs/PTs into digital information.

IEC 61850
Single Line Diagram
EXISTING CONTROL & PROTECTION RELAYS

The 6MD66 high-voltage bay control unit whose functions are:

Switchgear interlocking

Measured-value processing

Metered values

Indication / measured value blocking

Communication

and many more.
RELAYS REPLACEMENT FOR IMPLEMENTATION OF SAS
6MD66 Bay Controller Unit
The 7SD522 relay provides full scheme differential protection and incorporates all functions usually required for the protection of power lines whose functions are:

Differential Protection (ANSI 87L, 87T)

Thermal Overload Protection (ANSI 49)

Distance Protection (ANSI 21,21N)

Power Swing Detection (ANSI 68, 68T)

Direct Transfer Tripping

Ground(Earth)-Fault Protection(ANSI 85-67N)

Backup Overcurrent Protection (ANSI 50, 50N, 51, 51N)

and many more.




RELAYS REPLACEMENT FOR IMPLEMENTATION OF SAS
7SD522 Bay Protection Unit.
Bay level includes protection and control IEDs (intelligent electrical devices) of different bays such as circuit breakers, transformers, and capacitor banks.

Bay level devices

collect data from the same bay and/or from different bays and transfer the information to other bays and station level and

also perform actions on the primary equipment in its own bay.

Bay Level Configuration
DIGSI 4 is used to set individual function parameters, such as protective settings, during operation via your PC.

Digsi 4 particularly supports the IEC 61850 standard for communication between substations and IEDs.

Digsi 4 can use existing hardware components and communication standards as well as their connections.

In Digsi 4 the parameters are set offline.
Digsi 4
CONFIGURATION OF BAY LEVEL Devices

enable and disable the functions of prevailing system conditions.

assign the parameters of Power System.

set the protection functions.


Modifying the Settings of protection functions
Allocating information items via Masking I/Os
modify existing interlocking logics or
create new ones,

create group indications,

create alarm messages

and many more.


Default and Control Displays are illustrations that can be shown on the display of your SIPROTEC 4 device, provided.
allocate information items to sources and destinations,

add user-defined information items and information groups.
Editing Default and Control displays
Creating logic functions via CFC
It is used to

configuring and parameterizing IEC 61850 stations.

manage subnets, network communicators and their IP addresses and to connect the information items of different communicators.



IEC 61850 System Configurator


SICAM PAS meets all the demands placed on a distributed substation control system.

SICAM PAS particularly supports the IEC 61850 standard for communication between substations and IEDs.

SICAM PAS can use existing hardware components and communication standards as well as their connections

SICAM PAS controls and registers the process data for all devices of a substation


SICAM PAS
At station level all the information from bay level collected and monitored then further passed on to Network Control Centre

switching of the substation is controlled from station level.
STATION LEVEL CONFIGURATION
During configuration, you insert all components required for your station. In addition to the bay devices, these also include the connections to the control center and the SICAM PAS CC HMI
The configuration and parameterization of your station.

The exchange of configuration data

We can define what information is available for communication with higher-level control centers and for system management.


CONFIGURATION OF STATION LEVEL

In this we define which information from the bay devices shall be used and whether it must be transmitted to the control center or used by the PAS CC HMI

Mapping
In the SICAM PAS system, SICAM PAS CC performs the control and display functions of the process information of your station.

Functional and spatial interactions of your station components are represented conveniently in the overview and station diagrams of SICAM PAS CC.

State changes of process information and control actions are logged chronologically in message lists, such as alarm and event lists.

SICAM PAS CC

A technical study of the proposed design has been performed and the conclusion is that this design can be achieved with existing technologies.

Conclusion
The proposed scheme has several merits in designing the substation of future.


Intelligent decisions.

Enhanced station level
information
power quality,
condition monitoring
fault situation analysis
Reliable and accurate data collection.

System visibility.

Wide area monitoring.

Increase reliability & Cost effective.
Supervised by:
Prof. Dr. Zubair Ahmed Memon

CONFIGURATION OF BAY LEVEL Devices
Full transcript