Study Committee B5 Protection and Automation CIGRE ...€¦ · protection and automation cigre activities and advances in protection and substation automation ... lei tu ng sha up

De Mesmaeker Ivan (CH)

Study Committee B5 Protection and Automation

CIGRE ACTIVITIES AND

ADVANCES IN PROTECTION AND SUBSTATION AUTOMATION

De Mesmaeker Ivan(Switzerland)

Chairman of CIGRE-SC-B5 “Protection and Automation”



Table of Contents

•I CIGRE SC-B5•II Trends in Protection and Substation Automation•III Outlook /Dream or reality•IV Conclusion



Table of Contents

•I CIGRE SC-B5•Scope of B5•Mission of B5•Organization of B5•(Preferential subjects Paris 2002)•(Preferential subjects Sydney 2003)•Preferential subjects Paris 2004•Preferential subjects Calgary 2005




De Mesmaeker Ivan (CH)Hindle Paul (UK

A1 Rotating machines (SC11)A2 Transformers (SC12)A3 High voltage equipment (SC13)B1 Insulated cables (SC21)B2 Overhead lines (SC22)B3 Substations (SC23)B4 HVDC and power electronics (SC14)B5 Protection and automation (SC34)C1 System economics and development (SC37)C2 System Control and OperationC3 System environmental performance (--)C4 System technical performance (SC36+33+38)C5 Power supply regulation and trading (SC38)C6 Distribution system and dispersed generation (--)D1 Materials and technologies for power systems (SC15)D2 Information systems and telecommunication

for power systems (SC35+39)

Study Committees of CIGRE


Study Committee B5 Protection and AutomationCIGRE SC-B5 / Scope:

Principles, design, application and management of power system protection, substation control, automation, monitoring and recording - includingassociated internal and external communications, substation metering systems and interfacing for remote control and monitoring


Study Committee B5 Protection and AutomationCIGRE SC-B5 / Mission:

- Promotion of continued development and exchange of experience for safer and more effective operation of power systems

- To be first international reference for power system protection and substation automation issues, synthesizing state-of-the-art practices and developing recommendations


Study Committee B5 Protection and AutomationCIGRE SC-B5 / Organization

The Study Committee B5 consists of

• 4 Advisory Groups (AG) and 1 Strategic Advisory Group

• 22 Working Groups (WG) or Task Forces (TF)

The following diagram shows the organizational structure. Each block contains the name of a group and its convenor (group leader).



Cigre/B5/Dec 2004

B5Chairman: I. De Mesmaeker

Secretary: P. Hindle

AG B5-02Protection & Monitoringof Main Plant & Circuits

M. Sachdev (CA)

AG B5- 01Substation Automation &

remote control J M Ordacgi Filho (BR)

AG B5-03 Monitoring, metering, recording & Overall System Prot.G.J.Amantegui (SP)

AG B5-04Asset & Info. Managt., Training & Education

F Koers (NL)

WG B5-02: Coordinationof digital relays/ conv.CTsS. Holst (SE)

WG B5-13: Acceptable functional integration in HV SS‘sA Apostolov (US)

WG B5-01: Autoreclosing& local system restorationI. Gardiner (UK)

WG B5-18: Guide for spec & evaluation of SSC P. Rietman (CH)

WG B5-15: Distance protection functionsD.A. Tziouvaras (US)

WG B5-03: Fault and disturbance analysisJ. Martinez Oterino (ES)

WGB5-20: New trends for auto fault & dist. analysisM Kezunovic (US)

TFB5-08: P&C for dispersed gen. & impacton Transmission J. De Cock (BE)

WG B5-17: Software models for EMTP AnalysisT.S. Sidhu (CA)

WG B5-21: New localP&C approaches to minimise impact of system distubances A H Abu Bakar (MY)

December 2004Cigré B5

WG B5-04: Techniques for prot. & monitoring generating plantG. Benmouyal (CA)

WG B5-16: Modern Techniques for BBPZ. Gajic (SE)

TF B5-03: Engineering tools for protective relayM. Kezunovic (US)

WG B5-07: Techniques for prot. & monitoring transmission linesS Chano (CA)

WG B5-10: Protection of series compensated linesJ. Zakonjsek (SE)

WGB5-08: Optimised useof Self-checking P.Leushuis (NL)

TF B5-06: S/W Cert. & version management ?? (NL)

WGB5-19: Protection relay coordinationH. Kameda (JP)

WG B5-11: Introduction of IEC61850 and its impacton P&C F. Cobelo (SP)

WG B5-09: Remote on-line Management P & C, D. Holstein (US)

B5Strategic Advisory Group

WG B5-05: Transformer protection, monitoring and controlM. Sachdev (CA)

TF B5-04: High Impedance Faults I Oranguren (ES)


Study Committee B5 Protection and AutomationCIGRE SC-B5 / Last publications

-2003:Optimisation of protection performance during system disturbanceTechnical Brochure 232 / ELECTRA August 2003

Conformance testing guidelines for communication in substationsTechnical Brochure 236 / ELECTRA October 2003

Substation Automation: beyond communication standardization ELECTRA December 2003



-2004:Report about B5 Colloquium in Sydney 2003ELECTRA April 2004

WG B5-07: Substation Automation Why and how Brochure 246 / ELECTRA April 2004

TF B5-05: Extracting, distributing relay dataELECTRA August 2004



-2005:WG B5-01: Auto-reclosing and Local System RestorationBrochure ??? / ELECTRA ???

How to use IEC 61850 in Protection and AutomationELECTRA ???

……???


Study Committee B5 Protection and AutomationCIGRE SC-B5 / Preferential subjects (Paris 2002):

- Cost Benefits of Substation Automation Systems

- Refurbishment of Protection and Substation Control:Experiences and strategies



-PS1: Automation of New and Existing Substations

-PS2: Fault and Disturbance Data Analysis

-PS 3: Modern Distance Protection Functions and Applications

CIGRE SC-B5 / Preferential subjects (Sydney 2003):



- Use and Benefits of Information Technology (IT) in Substation Automation, Protection and Local Control

(Special Reporter: Germany)

- The needs for software aids/tools in Protection Management and Engineering: application, databases, testing/certification

(Special Reporter: Malaysia)

CIGRE SC-B5 / Preferential subjects (Paris 2004):



-Transformer Protection, Monitoring and Control(Special Reporter: Canada)

- Specification and Evaluation of Substation Automation Systems

(Special Reporter: US)

- Protection and Control of Series Compensated Networks

(Special Reporter: South Africa)

CIGRE SC-B5 / Preferential subjects (Calgary 2005):



Table of Contents

• II Advances in Protection and Substation Automation•1. Introduction of numerical solutions•2. Lessons learnt (2002, 2003 and 2004)•3. Impacts of integrated numerical solutions



1. Introduction of numerical solutions

Introduction of numerical technology:- mainly done on a piece per piece replacement

Introduction of monitoring systems:- using communication and recording capabilities

Introduction of numerical Substation Automation:- in progress- has more impacts than only functional aspectsin protection and control



E

Mimic control board

NCC InterfaceSER / Fault Recorder

Protection Cubicle

Mar

shal

ling

Control CubicleRelays for control / logic

Transducers, MetersSwitches, Lamps

Annunciators, Terminals

Interbaybusd gi ta l

Tx2

Rx1

Tx1

500SCM

01

Rx3

Tx3

Rx2

Tx2

Rx1

Tx1 di gi t al

NCC / RCC

MicroSCADA

ABBPower Automation AG COM581

C

CommunicationConverter

ABBPower Automation AG RER 111

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

=AD17-KB2Steuerung / SchutzFällanden

Feldsteuergerät REC2 16 mit Messung und Synchrocheck

LEITU NGSHA UPTSC H UTZ R EL316* 4 PRÜFS TECKE R

I

0SCH UTZ EI N/A US

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SAMMELSCHIE NENS C HUTZ REB500 RESER VESC H UTZ

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220VD C SPAN N UNG SYS 1 2 20VD C SPA NN U NG SYS 2

SYNC H RONISIE RU NG HA ND

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2 x 220/24V D C/D C SPA NN UNGSVE RSORGU NG

-X1

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=AD17 FÄLLANDEN2a1a

100 3002000

MESSANWAHL0R-N

T-N

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S-NS-T

SPANN U NG

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+480-480

BLIND LEISTU NG

WIRKLEIST UNG

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-JA1( L2121 ) -JA2( L2122 )

-JA5( L2126 )

-JA6( L2136 )

LS HYDRAULIKPUMPEZU VIELE ANLÄUFE

LEISTUNGSSCHALTEREINSCHALTKREIS

BLOCKIERT (CO)

ANTRIEBSMODULEAUSGANGSRELAISSTÖRUNG

SCHALTHANDLUNGUNVOLLSTÄNDIG

SAMMELSCHIENENSCHUTZGERÄTSTÖRUNG

ACHTUNG !SCHALTHANDLUNGVERRIEGELT

SAMMELSCHIENEN-/SCHALTERVERSAGER-SCHUTZ AUSGELÖST

LEITUNGS-RESERVESCHUTZAUSGELÖST

LS AUSLÖSEKREIS-ÜBERWACHNUNG 2ANGESPROCHEN

LEISTUNGSSCHALTERPHASEN-DISKREPANZAUSGELÖST

LEISTUNGSSCHALTERAUSSCHALTKREISBLOCKIERT (O)

LS HYDRAULIKPUMPENLAUFZEIT

ÜBERSCHRITTEN

HORNQUIT

LAMPENTEST

ZUSTANDEIN

EIN AUS RÜCK-STELLEN

AUS-FÜHREN

ANTRIEBSSTEUERUNG

NORMALDIREKT

FERNLOKAL

LEISTUNGSSCHALTER/TRENNER/ERDER

POSITION GESTÖRT

220V DC / 230V AC SCHUTZ-STEUERSPG. 0 -SPANNUNG

LEISTUNGSSCHALTERSF -GAS NACHFÜLLEN

LEITUNGS-HAUPTSCHUTZSTÖRUNG

LEITUNGS-HAUPTSCHUTZ AUSGELÖST

24V DC PROZESS INTERFACE

SPG. STÖRUNG

LS HYDRAULIKFEDERSPANNUNGSTÖRUNG (OCO)

LS AUSLÖSEKREIS-ÜBERWACHNUNG 1ANGESPROCHEN

100 3002000100 3002000

FERNLOKAL / NORMAL

LOKAL / DIREKT

SAMMELSCHIE NENSP AN NU NG

-JA4( L2111 )

PUMPENRÜCK-

STELLEN

R

ST

SAMMELALARME BETRIEBSZUSTAND

R

S

T-JF1( L2151 )

( L2141 )

SPANNUNGSWANDLERSICHERUNGSÜBERW.

ANGESPROCHEN

FELDSTEUERGERÄT

ALARMQUIT

SIGNAL-/ALARMANLAGE

TRENNER/ERDERMOTORSCHUTZANGESPROCHEN

500 150010000R

TS

STROM

RELAISHAUS 2RELAISHAUS 3

RELAISHAUS 4

500 150010000500 150010000

WANDLERALARM

GASSCHUTZ

KOMBIWANDLER

FEDER / SF

EIN-BLOCKIERTAUS-BLOCKIERT

Control/Protection Cubicles

-Q1

-Q0

-Q8

Feed

er M

arsh

allin

g

-Q9

-Q2

2. Economical justification of SA


Study Committee B5 Protection and Automation2. Economical justification of SA

n Comparison of systems

Conventional

Semi-conventional

Fully numerical


Study Committee B5 Protection and Automation2. Economical justification of SAn Comparison of systemsResult:Reduction of costs (100%/84%/75%)

•Integration of functions

• Serial communication

• Allocation of functionsExperience gained: Functions as much as possible decentralised to bay level



n Testing and commissioning:


8 % of SA overall cost

2 % of SA overall costs

n Training:



n Delivery timesReport 23-306 during CIGRE Session in Paris 2002„Experiences with substation optimisation considering new technical and economical aspects“by ABB and Alstom„A reduction of project cycle times is possible if the processes on both sides (utility/manufacturer) are simplified.A simplification ... can be achieved by using pre-designed substation solutions ...“




2. Economical justification of SAnMaintenance costs

PS 1 Session Summary: Performance and cost benefit

Paris, August 22, 2002 slide 12

Question 12: Numerical Substation Automation Systems provide better possibilities to obtain relevant information when a fault occurs. In which way will this information availability influence the maintainability and fault analysis process of the protection and local control? Has the maintenance practise changed with numerical equipment and what cost could be saved?

Prepared contributions

Mr Y Aabo, Norway The cost for operation and maintenance is significantly reduced with IT numerical substations. Information processing will be much more important to reduce the maintenance cost.

Mr H Kuribayashi, Japan Statistics show that Self supervision detects 77 % of the faults in numerical relays, 12 % by manual testing and 11% by fault analysis from system faults

• Cost reduction• Self supervision• Increasing use of fault analysis


Study Committee B5 Protection and Automation2. Economical justification of SAnMaintenance costs

• Periodical tests significantly reducede.g. testing on site every 5 years.

• The fault statistic shows us that most of the faults are not in the unit itself but in the surrounding system.

• The selfmonitoring covers normally more than 90% of the unit.

SC34 COLLOQUIUM in Florence (Italy), October 1999:

Report 110 „Integration of protection, control and monitoring functions–Experiences and future requirements from utility point of view“BKK, Norway,Statnett Norway,Energy Research Norway


Study Committee B5 Protection and AutomationMaintenance costs

• Periodical tests significantly reduced



* CENS: Compensation for Energy Not Supplied

• Minimizing of energy not supplied

• Reduction of interruptiontime

• Lower cost associated with CNES*

2. Economical justification of SAnAdded value



• Large cost saving resulting from the substations being unmanned.

• Lower probability of human errors• Communication links outside the substation if rented

n Operating costs2. Economical justification of SA



- Big expectations concerning IEC61850- Necessity of retrofit strategy (generally only obsolescence)

- “Complexity” of manufacturer solution(customer specification to be changed, better HMI)

- Integration of P & C (bay level) in transmission: about 50% of utilities

- Cost benefits mainly at system level

- Human errors >50% (unwanted operations)

3. Lessons learnt:Preferential subjects of B5 (Paris 2002)



PS 1 Session Summary: Performance and cost benefit

Paris, August 22, 2002 slide 7

Question 7: The fault statistics in Norway shows that half of the unwanted operations are caused by human activities during operation of the power system, or related to testing and setting of the protection and local control system. Are there similar experiences in other countries, and what can be done to improve the situation?Prepared contributions

Ms Gerd Kjølle, Norway Numerical less unwanted, more missing operations. More human errors in numerical systems.Agrees with Mr Messing; Keep the people out of the stations

Mr V T Nguyen, Canada Human errors 50 % of unwanted operations i Hydro-Quebec system. Using ergonomic and cognitive engineering to improve situation

Mr G Koch, Germany Verification of set points, after changes in the power system status are neglected. Today tools are available for quick set point verification.

Mr L Hossenlopp,France Inflation in manufacturer specific parameter names creates confusion. Naming convention in IEC 61850 will improve situation as well as improved engineering tools.

• Human errors contribute to 50 % of unwanted operations




„... Most of the papers emphasise the importance of a total Information Management ... to achieve the main goals of:- Improved profitability

- Reduced outage time- Reduced maintenance

- Reduced administration costs- One data original- Data base management that enables the information exchange in the utility intranet“




- PS1: Automation of New and Existing Substations

•Utilities adopting implementation strategies

•Requirements:Basic up to high functionality

•“Standardised” bay solutions

•Multiple utilisation of data

•IEC61850, the different SA architectures remain

3. Lessons learnt:Preferential subjects of B5 (Sydney 2003)



- PS2: Fault and Disturbance Data Analysis

•Simple cases, in an automatic way (short reports)Complex cases

•Differences between DR equipment and integrated DR functionality diminishing

•Demand for “new” functionality:e.g. high –accuracy fault location

•New equipment for new/special applications





•Autoreclosing/Synchrocheck:very often included in the line protection scheme

•Power Swing Block. / Out of Step: to be differentiated





•DEF very often integrated in Main 1 and Main 2

•Integration of Breaker Failure Protection (BF):level of integration remains a discussion pointBF separated in dedicated device, BF in Main 1 and in Main 2, BF in Busbar Protection Scheme




PS 1: Use and benefits of Information Technology (IT) in SA, Protection and Local Control

•IT capabilities sometimes not used because of organisational issues: control department separated from the protection department, missing infrastructure, lack of knowledge•Functional integration will going on due to economical aspects. Changes of design and operation philosophies are necessary to reach full benefits




PS 1: Use and benefits of Information Technology (IT) in SA, Protection and Local Control

•IEC 61850: - Many contributions from vendors but few from

utilities (typically for new technologies)- Utilities require tools - Simple maintenance of system databases, reusable

configuration information- New sensors with standardized interfaces offer a

high potential for cost reduction




PS 2: Need for Software tools in protection management and engineering

•Even if good tools are available, the personal judgment is needed for complex cases•Rules for setting of distance zones: necessity to consider complex cases•Replacement of components, updatings of protection relays: audits instead of new homologation•SPS: generally positive feed-back to prevent out-of-step, frequency instability and overload phenomena•IEC 61850: Statements about available products



Study Committee B5 Protection and Automation4. Impacts of integrated numerical solutions

•4.1 Integration

•4.2 Power System Management

•4.3 Specifications

•4.4 Organization



4.1 Integration:- Integration of ever more functions in less equipment

- Discussion in Paris in August 2002:(Session CIGRE - B5)Integration of Protection and Control

Distribution level applications: acceptedHigh voltage level applications: controversial



12

4

5

8

39

68 C

ubic

les,

>18

0 D

evic

es

è Line

èTransformer

è Busbar

è Feeder

è Control

1960 1970 1980 1990 2000 2010?

Figures for Reference Station 6 Feeder 220kV / 8 Feeder 16kV

12

4

3

8

39

66 C

ubic

les,

>16

0 D

evic

es

6

4

3

4

39

56 C

ubic

les,

>14

0 D

eviv

es

6

2

3

4

32

47 C

ubic

les,

>10

0 D

evic

es

13 C

ubic

les,

>5

0 D

evic

es

3

1

7

2

4

4 Cubicles, “Soft” Devices

4. Impacts of integrated numerical solutions



System A

System B

System A

System B

Existing System

Modern System

- Multi-functional unitswith comm. capabilities

- Secondary technique asa whole (protection,control and monitoring)

- Communication capabilities(data collection and dataaccess)

- Decentralised architecture




Busbar-Breaker-failureProtection

Busbar Protection

Busbar-Breaker-failureProtection

Main 1/ Main 2or Backup.Feeder Protection

Main 2/BackupFeeder Protection

Main 2/BackupFeeder Protection

Main 2 or Backup Protectionin 1BB / 2BB Substations

Main 1/ Main 2or Backup.Feeder Protection




4.2 Power System Management



4.3 Specifications:- Common approach covering

the whole secondary technique- Moving away from a box-to-box way of thinking- Specifying the functions instead of the final solution- Considering the goals of the utility- Considering the total life cycle costs- “Standardised” predesigned solutions

4.4 Organization:- Closer cooperation (or even merging) of protection and control departments


Study Committee B5 Protection and AutomationIV Outlook / Dream or reality

Previous dreams will become reality:

-Interconnection of devices from different manufacturers (interoperability)

-Data interconnection of all devices and systems from the substation up to the administration office.

-Full use of communication capabilities at all levels (also internet/intranet and WEB-based applications)



Previous dreams will become reality:

-System Protection Schemes

-Comprehensive monitoring and diagnosis functions for the primary and secondary equipment



The goal of the IEC 61850 standardThe goal of the IEC 61850 standard

Free configuration The standard shall support different philosophies and allow a free allocation of functions e.g. it must work equally well for centralized (RTU like) or decentralized (SCS like) systems.

Interoperability The ability for IED’s from one or several manufacturer to exchange information and use the information for the their own functions.

Long term stability The standard shall be future proof, i.e. it must be able to follow the progress in

communication technology as well as evolving system requirements.

IV Outlook / Dream or reality



LON

MVBRIO, PISA, etc.

Stationgateway

MicroScada,COM, etc.

Stationcomputer

HM I

IEC 61850 replaces all buses: LON, MVB, SPA, Profibus, DNP3.0,etc.

RE. Control Protection Protection& Control

Control Protection

Process Interface Process Interface Process Interface




IEC

IEC

Stationgateway

Stationcomputer

HM I

IEC 61850 is both Station and Process Bus

Control Protection Protection& Control

Control Protection

Process Interface Process Interface Process Interface




Part 6Substation Configuration Language (SCL)

Communication model (Data model and Services) Part 7

Communication requirements Part 5

System and Project management Part 4

Glossary Part 2

Introduction and overview Part 1

General requirements Part 3

Part 10Conformance testing

Impact on tenders and

product mgmt.

Impact on engineering

IEC 61850: Impacts not only on communication !

Part 9

Process bus

Teil 9-1 : Mapping to point-to-point connections

Teil 9-2 : Mapping for bus connections

Part 8

Part 8-1 : Mapping for MMS-TCP/IP-Ethernet

Teil 8-x : for Future Use Station bus




u L System LN (2)

u P Protection (28)

u R Protection related (10)

u C Control (5)

u G Generic (3)

u I Interfacing and archiving (4)

u A Automatic control (4)

u M Metering and measurement (8)

u S Sensor and monitoring (4)

u X Switchgear (2)

u T Instrument transformers (2)

u Y Power transformers (4)

u Z Further power system equipment (15)

Examples:u PDIF: Differential protectionu RBRF: Breaker failureu XCBR: Circuit breaker

u CSWI: Switch controlleru MMXU: Measurement unitu YPTR: Power transformer

IEC 61850: Logical node groupsIV Outlook / Dream or reality



Data objects and data attributes

Protection I> èPTOC Start StrTrip Oper. . .

L1 phsA

L2 phsB

L3 phsC

etc

Protection Activation Information



Device Example: Combined Protection and Control Unit

Device Example: Combisensor

Device Example: Circuit Breaker

Device Example:Station Workplace The mapping to

real devices

XCBR(Circuit Breaker)

TCTR(Current Transformer)

TVTR(Voltage Transformer)

CSWI(Switch Controller)

PDIS(Distance Protection)

IHMI(Human Machine IF)

IEC 61850: Logical NodesIV Outlook / Dream or reality



Circuit BreakerQ0_L1/XCBR

Gas density mon.Q0_L1/SIMG Primary technology

Secondary technology

ControlQ0/CSWIQ8/CSWIQ9/CSWI

Bay-HMIIHMI

IsolatorQ9_L1/XSWI

Gas density mon.Q9_L1/SIMG

Earthing SwitchQ8_L1/XSWI

Gas density mon.Q8_L1/SIMG

Distance ProtectionPDIS

IV Outlook / Dream or realityIEC 61850



Physical Device PISA_Q0_L3

Logical Device Q0_L3/XCBR

Logical Node XCBRPositionOperation CapabilityOperation Counter

Position Sensor AlarmPump Supervision Alarm

Logical Node LN0LN StateSet Test Mode


IEC 61850



Local operation mandatorySwitch position mandatoryOperation capability mandatoryOperation counter optional…

Circuit BreakerXCBR

The objects are the functions, that the user needs and knows from everyday experience. They are called “Logical Nodes” in the standard. For example XCBR with all defined data:

Mandatory and optional Data are associated with all objects

Access to object and data is standardized (Services)

The Objects and Data are self describing

IEC 61850 defines objects, data and services




IEC 61850

Services define in a standardized way how data are accessed and transmitted

nread a value / attribute

nwrite configuration attributes

ncontrol a device e.g. by SBO

nevent oriented reporting

nlocal storage of events in a log

nget directory information

nfile transfer

nTransfer of GOOSE messages (Generic Object Oriented Substation Event)

nTransfer of sampled values (SV)


Study Committee B5 Protection and AutomationIV Outlook / Dream or realityIEC 61850nIEDs are engineered using manufacturer specific

IED configuration toolsnConfiguration tools translate the IED capabilities to

the SCL (Substation Configuration description Language)nSCL enables information exchange between the IED

configuration tools from different manufacturersnSCL secures backwards compatibility between the

different versions of IEDs and IED configuration tools


Study Committee B5 Protection and AutomationIV Outlook / Dream or realityIEC 6150 - Interoperability at the CIGRE exhibition in Paris (2004)



IEC 61850: example of architectureControl Center HMI Engineering

Ethernet Switch

Router

Relay A

Bay Controller

Conventional Switchgear

ConventionalCT / VT's

Relay B

Relay A

Bay Controller


Relay B


IEC 61850-8-1

Example




IEC 61850: example of architectureControl Center HMI Engineering

Router

Relay A

Bay Controller



Relay B

Relay A

Bay Controller


Relay B


IEC 61850-8-1

Ethernet Ring with Switches Example






Wide Area Monitoring & Protectionprecise dynamical measurement

dynamic wide area view





Wide Area Monitoring & Protection- precise dynamical measurement

- dynamic wide area view

SCADA / EMSstatic viewActions initiated by long term phenomena


Reaction time

Conventional Protectiondirect & local trip


Coordinated

Uncordinated


SCADA / EMS- rather static view- Actions initiated by long

term phenomena


Conventional Protection- direct & local trip

DataWide Area Monitoring & Protection



IV Outlook / Dream or realityn Wide Area Protection and

Monitoring System focusing on power system security

Benefitsn Enhance capacity of

transmission corridorsn Improve power network

stability and prevent outages

n Featuresn Voltage stability monitoring

& predictionn Angular/Frequency stability

monitoringn Precise calculation of available

transmission capacityn Prevention of Wide

Area Disturbances



Achieved timestamp accuracy : 1 MicrosecondAbsolut accuracy error: < 0.1 degree

Dynamic & synchronized Information from substation to network controlIV Outlook / Dream or reality



Wide Area monitoring




Resynchronization of the UCTE zones 1 and 2

10 October 09.33

Workstation in Coatia

Wide Area monitoringIV Outlook / Dream or reality


Study Committee B5 Protection and AutomationWide Area monitoring



Wide Area monitoring nAllowing fast and

precise actions to prevent blackouts

n Stabilizing measures to maintain system integrity

nOptimized utilization of transmission capacity

Future steps



Study Committee B5 Protection and AutomationV Conclusion

- Economical pressure is the driving force for utilities and manufacturers

- Technology: More powerful equipment, higher degree of integrationNew solutions using communication capabilities(e.g. System Protection Schemes)

- Impact on the organization of utilities

- Secondary technique:the basic building blocks for an advanced power system management concept


Study Committee B5 Protection and AutomationV Conclusion

CIGRE B5 consider

the evolution of technologiesthe requirements of utilities



Thank you for your attention

Documents

Study Committee B5 Protection and Automation CIGRE ...€¦ · protection and automation cigre activities and advances in protection and substation automation ... lei tu ng sha up