1 gesa ge substation automation for the world. 2 substation automation > requirements >...

1

GESAGE Substation Automation

for the world

2

Substation Automation

> Requirements

> Protective relay hardware

> Protective relay logic

> Relay to relay data communication

> Local/Bay control

> WAN

> SCADA

Agenda

3

Requirements:

• Most up to date CPU’s yet expect 20 to 30 year MTBF.

• Built in programmable controller functionality

• High speed relay to relay data communication

• Expandable:

• I/O

• Multiple CT and VT Modules with the ability to calculate virtual sources

Solution:

•Modularity

Protective Relay

Introduction

4

Requirements:

• Reusable code to reduced development time

• Reduce training requirements: family of protective

relays with same touch and feel and common

feel and common hardware components

Solution:

• Design must be based on a Platform

Protective Relay

Protective Relay

5

• High speed relay to relay service part of a protocol suite optimized for Utility applications

• Redundant Star fiber configuration:

• elimination of single point failures

• Readily available proven LAN components

• Open Architecture

Relay to Relay Communications

Introduction

Primary

Back-up

6

• High speed HMI service part of a protocol suit optimized for Utility applications.

• Standard naming convention

• Direct connection to high speed substation LAN.

• User configurable graphics display.

• Primary graphic, control and monitoring functions

Local / Bay Control

Introduction

Local/Bay control

7

WAN Requirements

Substation 1 Substation 2

Substation 3 Substation 4

Redundant fiber WAN

Introduction

8

Supervisory Control and Data Acquisition - SCADA

Enterprise

• Budget accurately

• Asses cost of service

• Allocate capacity

• Faster service response

Operations

• Remote status and control

• Analyze power quality

• Identify events

• Receive fault records

• Target Maintenance

• Loading trends

Introduction

Information not Data:

9

Data Communications Hierarchy

Introduction

10


> Requirements


> Protective relay logic engine


> Local/Bay control

> WAN

> SCADA

Agenda

11

“The engine for substation automation”

The ‘Universal Relay’ Family

Protective Relay

12

FeederFeederTransformerTransformer

GeneratorGenerator

TransmissionTransmissionLineLine

Cost ($)Cost ($)

PerformancePerformanceUniversal

Relay BusbarBusbar

Feeder Line Transformer Generator

Busbar ControlPowerQuality

The Challenges of the ‘Universal Relay’

Application Software

Protective Relay

13

High-Speed Data BusHigh-Speed Data Bus

Po

wer

Su

pp

ly

CP

UM

ain

Pro

ce

ss

or

DS

P &

Mag

net

ics

DS

P p

roce

sso

r +

CT

/VT

s

DIG

ITA

L I/

OSt

atus

Inpu

ts /

Con

trol

Out

puts

AN

AL

OG

I/O

An

alo

g T

ran

sd

uc

er

I/O

CO

MM

UN

ICA

TIO

NS

(Eth

ern

et, H

DL

C, U

AR

T)

DisplayDisplay

KeypadKeypad

LEDModules

LEDModules

LEDModules

LEDModules

LEDModules

LEDModules

Modular HMI Panel

Six BasicModules

Universal Relay Architecture - ‘Modularity’

Protective Relay

14

19’’ Chassis(4RU high)

Physical Realization

Po

wer

Su

pp

ly

CP

UM

ain

Pro

cess

or

DSP

& M

agne

tics

DSP

pro

cess

or +

CT/

VTs

DIG

ITA

L I

/OSt

atus

Inpu

ts /

Con

trol

Out

puts

AN

AL

OG

I/O

Ana

log

Tran

sduc

er I/

O

CO

MM

UN

ICA

TIO

NS

(Eth

erne

t, H

DLC

, UA

RT)

ModularHMI

High-Speed Data BusHigh-Speed Data Bus

Modules

Protective Relay

15

Modularity... P

ow

er S

up

ply

Power Supply

•Wide input range •24 - 300 VDC•20 - 265 VAC

•High Efficiency SMPS•> 80%

CPU

CP

UM

ain

Pro

cess

or

•High-speed 32-Bit RISC CPU

•> 50 MIPS, up to 120 MIPS

•FLASH memory •Easy firmware upgrades

High-Speed Comms support•10/100Mbps Ethernet LAN•Redundant Fiber

DSP + CT/VT

DS

P &

Mag

net

ics

DS

P p

roce

sso

r +

CT

/VT

s

•Modular CT/VT configurations • up to 8 CT/VTs

•High-speed digital sampling•>16 Bit A/D•> 64 samples / power cycle

•High-speed 16-Bit DSP•> 32 MIPS, up to 80 MIPS

Protective Relay

16

•Control outputs •Solid State•Electromechanical - multiple types•Fast activation speeds (< 4ms)

•Status inputs•Dry and Wet contacts•18 - 300 VDC•Fast detection speeds (< 4ms)

DIG

ITA

L I/

OSt

atus

Inpu

ts /

Con

trol

Out

puts

Digital I/O

•Transducer type inputs •± dcmA•±Voltage•Resistive

•Outputs for Legacy SCADA•± dcmA

•Support multiple I/O configurations

Analog I/O

AN

AL

OG

I/O

An

alo

g T

ran

sdu

cer

I/O

Communications

CO

MM

UN

ICA

TIO

NS

(Eth

ern

et, H

DL

C, U

AR

T)

•High-speed Serial•Asynchronous (9600 - 115K Baud)•Synchronous (56K - 256K Bps)•Fiber Optical (Single/Multimode)•Channel Redundancy

Modularity...

Protective Relay

17

Inter-Module Communications

High-Speed Data Bus

High-Speed Inter-Processor Serial Data Bus: 16Mbps

High-Speed Serial Communications Bus: 10Mbps

High-Speed Parallel Data Bus: 80 - 100 Mbytes/sec

Multiple buses allow for high-performance:•Protection and communications without bottlenecks

Protective Relay

18

Scalability

Minimum

Maximum

Protective Relay

19

‘Box’ Capacity

CT/VT (I & V) inputsup to 3 modules

Status (Binary) inputsup to 6 modules

Control (contact) outputsup to 6 modules

Analog (Transducer) I/Oup to 6 modules

24 (max)

8/module

96 (max)

16/module

48 (max)

8/module

48 (max)

8/module

Protective Relay

20

Configuration/Flexibility

Sub-Modules

Protective Relay

21

Sub-Module Types

Current & Voltage

Control and Status I/O

Analog (Transducer) I/O

CT, VT

Optical, DigitalFuture

Future

Form-AForm-C

Solid-StateWet/Dry Input

Customer - ??

1mA, 4-20mA, 0-5mARTD (Pt, Ni, Cu)5V, Resistive

Future Customer - ??

Protective Relay

22

‘Upgradeability’/Serviceability

CT Shorting‘Clips’

Field Wiring Undisturbed

ModuleKeying

‘Plug n Play’

Easy ModuleDraw-out

Protective Relay

23

•L60 (Transmission Line: Phase Comparison) •L90 (Transmission Line: Current Differential) •D60 (Transmission Line: Distance) •F3x (Feeder: Multiple Feeders - Basic Protection) •F60 (Feeder: Comprehensive w Hi-Z) •T60 (Transformer: Comprehensive) •C30 (Control IED) •C60 (Breaker Management IED)

TRANSMISSION

DISTRIBUTION

The UR Family - One Common Architecture

•URPC (Entry Level HMI, Engineering Tool)•PMCS (Full Featured Systems HMI)

•G60 (Generator: Comprehensive > 100MVA)•B30 (Busbar: Basic 6 Feeder ) •B90 (Busbar: Comprehensive up to 30 Feeders)

GENERATION (Available in 2000)

SYSTEMS SOFTWARE

The UR Family

Protective Relay

24

The UR Family

Protective Relay

FEATURES

• FlexLogic™

• Distributed FlexLogic™

• Virtual I/O (reduce hardware cost)

• Expandable I/O

• Flash monory for field upgrades

• Drawout modules for serviceability

• Common modules (reduce spares cost)

• Test mode for forcing contact I/O states

• IRiG-B time synchronization

25


> Requirements




> Local/Bay control

> WAN

> SCADA

Agenda

26

UR FlexLogic™ Engine

RemoteRemoteInputsInputs

Protective Relay

27

Introduction to Flexlogic

AND

Pickup

Forward

Remote Forward

AND

Operate

Assign Virtual

Protective Relay

28

Protection Element

Enable

Block

Source

Pickup

Operate

Drop Out

Function Inputs

Function Outputs

Protective Relay

Introduction to Flexlogic

29

Introduction to FLEX Logic

AND

Protective Relay

30

OUTIN2

IN1

AND OUTIN2

IN1

NAND OUTIN2

IN1

OR

In1 In2 OUT

0 0 0

0 1 0

1 0 0

1 1 1

In1 In2 OUT

0 0 1

0 1 1

1 0 1

1 1 0

In1 In2 OUT

0 0 0

0 1 1

1 0 1

1 1 1

Truth Tables

Protective Relay

31

OUTIN1

NOR OUTIN2

IN1

XOR OUTIN2

IN1

NOT

In1 In2 OUT

0 0 1

0 1 0

1 0 0

1 1 0

In1 In2 OUT

0 0 0

0 1 1

1 0 1

1 1 0

In1 OUT

1 0

0 1

Truth Tables

Protective Relay

32

Timers

Protective Relay

Timer #

Pickup

Drop out

Pickup Time

Drop out Time

33

Counters

Protective Relay

34

Counters

Protective Relay

35

FlexLogic Demonstration

Protective Relay

FlexLogic Demonstration

36

FlexLogic™ Navigation

Protective Relay

37

FlexLogic™ Navigation

Protective Relay

38

Contact Outputs

Protective Relay

39


> Requirements




> Local/Bay control

> WAN

> SCADA

Agenda

40

LAN: Local area network

WAN: Wide Area Network

Nomenclature

Relay to Relay Com

41

Nomenclature

Protocol: A common set of rules to govern the exchange of data

between nodes on a network.

It determines:

• Initialization of data link

• Services that are supported

• flow control

• Frame format and sync

• error control

42

Communication Protocols and Standards

Messaging Services

• Provides “Common Services” for communicating information including notification of delivery or non-delivery of a message and the reason why not

• Types of services:-Initiate Communications-Identify-Define Data-Write Data-Program Invocation-Etc.

• Existing Standards: FMS, MMS, DNP, IEC

Data Communication Hierarchy

43


Manufacturing Message Specification (MMS) • Internationally standardized messaging protocol for real time exchange of data and supervisory and control information between networked devices.

• ISO 9506 standard

• Independents from the application function being performed

• Independents from the developer of the device or application • Generic to be appropriate for a wide variety of devices and applications:

PLC Robot Protective relay

• Based on the OSI model

MMS services and messages are identical

44

MMS Service Specification

• Defines a set of objects that can exist within a device.

• Defines a set of communication services to access and manipulate those objects.

• Defines the behavior of the device

to those communication services.



45

MMS Services

• Get Object

• Change Object

• Determine Attributes

• Create Object

• Delete Object



46

Peer to Peer• Client / Server

• Publisher/ Subscriber

Master / Slave• Request / Response

• Response Only

Basic Communication Relationships

Relay to Relay Com

47

LAN Topology: Token RING

Relay to Relay Com

48

LAN Topology: STAR

IED

IED

IEDIED

IEDSwitch

Active/ Passive

IED

Relay to Relay Com

49

Architecture: Token Bus

• TOKEN to gain access to LAN

50

LAN Access: Token

51

LAN Access: CSMA/CA

1

1

01

0

0

Crash

Relay to Relay Com

• CSMA / CA• Carrier science multiple access with crash detection

52

Communications: OSI Model

PHYSICAL

APPLICATION

SESSION

PRESENTATION

NETWORK

TRANSPORT

DATALINK


53

AP DATA

MMS MODBUS

PHYSICAL

APPLICATION

SESSION

PRESENTATION

NETWORK

TRANSPORT

DATALINK



54

AP DATA

MMS MODBUS

PHYSICAL

APPLICATION

SESSION

PRESENTATION

NETWORK

TRANSPORT

DATALINK

AP DATA



55

Utility Communication Architecture (UCA) and Substation Automation

Relay to Relay Com

56

Utility Communications Architecture Version 2

Objective:

• Establish a suite of protocols to meet utility communications needs

UCA 2.0

Relay to Relay Com

57

• GE Power Management

• Basler

• Cooper

• Beckwith

• Tasnet

• SEL

• GE Harris

• Siemens (HMI)

• L&G

• Doble

• Dranetz / BMI

• Modicon / Square D

• ABB

• Alston

Participating UCA Vendors

Relay to Relay Com

58

• American Electric Power (AEP)

• Indianapolis Power & Light

• Ontario Hydro

• Northern States Power

• Tampa Electric

• ComEd

• Cinergy

• Baltimore Gas & Electric

• GPU

• Nuon

• Enetergy

• TVA

• Duke

• Boston Edison

• Union Electric

• Florida Power Corp

• Southern California Electric

• Wisconsin Electric

• ESKOM

• Polish Power Grid

Utilities Participating in UCA

Relay to Relay Com

59

UCA 2.0 is defined by a set of Documents

• Introduction

• Communication Profiles

- TCP/IP

- OSI

- Serial

• CASM

Common Application Service Models

How MMS Services are used (MMS = Manufacturing Message Specification)

• GOMSFE

Generic Object Models for Substation and Feeder Equipment

UCA 2.0 Defining Documents

Relay to Relay Com

60

UCA Features

• Client/Server Multiple Connections

• Common Data Objects that can be extended by each vendor

• File Services

• Time Sync

• Reporting

• GOOSE (Generic Object Oriented Substation Event)

• Peer to Peer Communication (Remote I/O is a cast message)


Utility Communication Architecture - UCA 2.0

61

7-LAYER UCA MODEL

CSMA/CD

(8802/3)

Token Bus

(8802/4)

TokenRing

(8802/5)

MMS

ACSE

FTAM VT DS MMS1988 CMIP

ROSE RTSE

Connection-orientated Presentation

MHS1984

Connection-orientated Session

Connection-orientated Transport 0 4

Connectionless Network

ES - IS Routing X.25 Packet Layer

ISDNQ.931

LLC 1

FDDI

HDLCLAPB

V.35EIA -232-D X.21

ISDNInterfaces

ISDNLAPD



62

UCA Data Access (Name - based)

Data ObjectClass

Functional Component

DataItem

Attributesr/w m/o

IOCSTSG Pu

PuDelTimDoDelTim

COCFDC

To access the Phases IOC 1 PickupRead PhsIOC1.SG.Pu



63

GOMSFE

Generic Object Models for Substation and Feeder Equipment

Models defined for:

Protection Elements - P IOC- PTOC- PDIS- RSYN- etc.

Metering - PXMU

Generic Analog/Digital I/O etc.



64

Trip Message(GOOSE)

Blocking Message(GOOSE)

RELAY #1 RELAY #2 RELAY #3L 9 0L I N E D I F F E R E N T I A L R E L A Y L 9 0L I N E D I F F E R E N T I A L R E L A Y

L 9 0L I N E D I F F E R E N T I A L R E L A Y

UCA 2.0 GOOSE MESSAGE

Relay to Relay Com

BreakerTrip Output

Input delay (4ms at present)+Tx/Rx and processing (Typically < 4ms at present)+Output delay (0.6 ms for Fast Form C)

= 8.6 ms

External Trip Delay:

65

UR Communications Profiles

Modbus/TCP/IP/Ethernet UCA 2.0 (MMS/Ethernet)

Modbus/UART/(RS485, RS232, Fiber)

RFC1006 - Presentation

IEEE 802.3 (10BaseFL)

MMS

RFC1006 - Session

TP4

CLNP

IEEE 802.2 (CSMA/CD)Ethernet

RS232, RS485, Fiber

UART - 8 Bits, 1 Stop Bit, No Parity

ModBus

NOT Implemented/Required

MMS, ModBus

TCP/ IP, UDP

IEEE 802.3 (10BaseFL)


IEEE 802.2 (CSMA/CD)Ethernet

Telecom: DS0 (64kbps), T1, E1

RS422, G.703, Fiber

HDLC

Proprietary, ModBus,



PHYSICAL

DATA LINK

NETWORK

TRANSPORT

SESSION

PRESENTATION

APPLICATION

PHYSICAL

DATA LINK

TRANSPORT

SESSION

PRESENTATION

APPLICATION

NETWORK

PHYSICAL

DATA LINK

NETWORK

TRANSPORT

SESSION

PRESENTATION

APPLICATION

PHYSICAL

DATA LINK

NETWORK

TRANSPORT

SESSION

PRESENTATION

APPLICATION

66

Goose Message Demonstration:

Relay to Relay Com

Goose Message Demonstration

67

Redundant 10 Base F Bay LAN Topology

Fiber switches

Relay to Relay Com

68

Virtual outputContact input

AND

Contact inputAND

Virtual output

FlexLogic: Relay 1

Remote output

Remote I/O lab

Relay 2

Remote Input

Remote input Status Table

ALARM Light

Relay to Relay Com

69


> Requirements




> Local/Bay Control

> WAN

> SCADA

Agenda

70

Universal Relay Human Machine Interface - HMI

HMIHMI

HMI Demonstration:

• Static Text and Graphics

• Importing bit maps

• Change screens

• Analog signal monitoring

• Push buttons

• Lamps

71

Introduction

HMI

72

Static text and graphics

HMI

73


HMI

74


HMI

75

Importing bit maps

HMI

76

Importing bit maps

HMI

77

Importing bit maps

HMI

78

Change Screens

HMI

79

Change Screens

HMI

80

Change Screens

HMI

81HMI

Change Screens

82HMI

Change Screens

83

Inserting a Relay

HMI

84

Inserting a Relay

HMI

85

Analog Signal Monitor

HMI

86HMI


87HMI


88HMI


89

Standard Push buttons

HMI

90HMI


91HMI


92

Standard Lamps

HMI

93

Standard Lamps

HMI

94HMI

Standard Lamps

95

Breaker Symbol Animation

HMI

96


HMI

97


HMI

98

QuickPanel jr - Low Cost HMI

•Graphical user interface: single-line, metering, alarms

•Touch Screen: alarms control buttons

•Control multiple devices: Modbus Master via RS485

Modbus/RS485

HMI

QuickPanel jr

HMI

99


> Requirements




> Local/Bay Control

> WAN

> SCADA

Agenda

100

The UCA Substation

10MbpsDual Ethernet Fiber switch

Interoperable IEDs

Access to:•Enterprise•Internet


SlowerLegacy Devices

use Gateway

101

Inter Substation Communications

FSC(Fiber Optic System Communications)

•SONET Technology: 51/155 Mbps•Ethernet LAN ‘Bridging’ capability•Creates single Ethernet WAN•Redundant channels ensure reliability


102

InternetInternet

UR + UCA + Internet = New Possibilities

Remote monitoring and diagnostics:•Power Quality monitoring•Equipment Health (Breaker, Transformer) monitoring•Fault Analysis - data retrieval•Events and Alarm annunciation

The IEDs (Relays) are a ‘socket’ for providing information and services.


103

Internet Communications NOW!

View/Retrieve:•Metering•Events•Oscillography

Test a UR F60Feeder Management

Relay over the Internet


104


> Requirements




> Local/Bay Control

> WAN

> SCADA

Agenda

105

GESA 2000

SCADA

107

W h y G E

• A Complete System Solution Supplier

• Global Focus With Engineering And Field Support

• Experience Over A Broad Range Of Industries

• A corporate commitment to six sigma quality

• Financial Strength

Dedicated to bringing the best Automation solutions to our customers

• Power system consulting

• Application design

• Project management

• Integration services

• Startup and comissioning

• Project financing

• Asset maintenance

• Remote diagnostics

SCADA

Substation Automation System Solutions

108

PLANNING

ENGINEERING

PROTECTION

MAINTENANCE

Real-time Analysis that Avoids Interruptions

Precise and Confident Operator Decisions in Restoring Service

Reduction in the Need for Costly Field Visits

More Effective Long Term Planning & Loading Decisions

Translating data into information at the users fingertips

SCADA

GESA - A System Solution that Delivers Productivity

109

The Challenge: Putting Information to Work

“On-Line Information”: Your key competitive advantage

• Fine-tune planning

• Streamline settlements

• Budget accurately

• Asses cost of service

• Allocate capacity

• Faster service response

• Remote status & control

• Analyze power quality

• Identify events, SOE

• Receive fault records

• Target maintenance

• Monitor loading trends

Enterprise Operations

SCADA

110

GESA 2000 The competitive solution

Sub-second response for Ethernet connected devices Dual master redundancy with automatic system control transfer Automatic interleaving of events and metering values Ethernet substation UCA 2.0 LAN Peer to peer communications Remote view nodes and web browser compatible HMI Interface Automatic oscillography upload Object oriented system tools for reliable, low cost reconfiguration Real-time system status and control execution

Maximize your Competitive Edge

SCADA

111

Three powerful dimensions to a complete Substation Automation Solution:

• Proven, “off the shelf” components that integrate

today’s IEDs

• Ethernet for data transport in the substation and to

remote sites

• Pre-engineered software, application tools and

device interfaces

GESA 2000

SCADA

112

Built Upon a New Generation Substation Architecture

HTML Wizards

HMI Screens

TrendsOscillographyViewer

EventViewer

FacilityDiagnostics

RemoteMonitor

SystemConfigurator

HT

ML

Gra

phic

s

OPC/ DDE/ CORBA

Interface to Corporate WAN/ LAN

UCA - MMSServer

Redundant Substation Ethernet LAN

Lev

el 1

- IE

Ds

Training/Testing

WEB Server - HMI View Nodes

Monitoring Protection & ControlInteroperability

Redundant Substation Ethernet LAN

Control

Interoperability

Lev

el 2

- In

teg

rati

on

Ho

st

U

ser

Open System Solution -- Relays, Software, Communications, Networking

LegacyServer

SCADAProtocols

PowerAnalysis

Tools

Event Logger

OperationalEfficiency/Reliability

ConfigurationTools

SCADA

113

Smart Screen “Wizards”• One Line Diagrams

• Event Logger

• IED Faceplate

• IED Tabular Values

• Annunciator Panel

• Alarm List with Sorting Feature

• Trending

Integration Productivity and Reliability

GESA 2000

SCADA

114

GESA 2000 Sequence of Event Log

• Time stamped to nearest milli-second• Synchronizable to GPS via IRIG-B• Automatic retrieval from IED to Host• Storage on host disk• Automatically forward to operations PC• Data sort capability included:

– Standard filters•Time•Device Type•Alarm Condition

– Custom filters per

your needs

Monitors and records all system event characteristics

SCADA

115

• Configurable alarm conditions

– Any present value can

drive an alarm

– Set range of operation

• Failure Alarms

– Equipment generated

– System generated

– Grouped per IED

• Remote Communication of Critical Alarms

Alarm Annunciator Panel

SCADA

117

Integrated Solutions to help you succeed

Interoperability

Peer to peer communications

Reliability of software objects and modules

Modularity of hardware modules and

components

Dynamic reconfiguration

Real-time state analysis and operation

SCADA

118

W o r l d w i d e Experience

North AmericaConEdPSE&G

PECO

Salt River

Europe & Africa

ERZ

South America

Electroperu

Inepar

Electronorte

EDENOR

Rio Light

Furnas

Asia Pacific

Aliu Zhou

Zhe Zhang

Guang Xi

SUBSTATION AUTOMATION INSTALATIONS AROUND THE WORLD

SCADA

119

What our Customers Require:That GE is Committed to Deliver

Critical to Quality Metrics

• Access to system application experts -- before, during and after a sale

• Open architecture solutions, built on industry standards - future upgrade path

• Thorough specification of the system to be delivered - fully understood by the user

• Deliver and commission on schedule; within budget - supplier and customer

• Effective operator training - establishing basic user competency

• Return on investment - work together to obtain the expected benefits

C u s t o m e r F o c u s e d

SCADA

120SCADA

Ordering On-line

1 gesa ge substation automation for the world. 2 substation automation > requirements >...

Documents

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family of protective

high speed hmi service

data communication expandable