© ABB Group March 20, 2012 | Slide 1

Smart Substation AutomationSET-1520 Sähköenergiatekniikan uudet sovellukset – Smart Grids

Jani Valtari, ABB Oy Distribution Automation, 22.3.2012

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Content

BackgroundDistribution automation and component lifecyclesClimate change and EU’s 20-20-20The market situation and technological advances

New requirements for substation automationAdvanced fault managementEfficient operation of the network, asset managementFuture-proof technologies, upgradeabilityLow life cycle costs

Architecture possibilities and building blocksCentralized protectionIEC61850 -standardBenefits of centralizationRe-allocating substation functionality

Summary

BackgroundDistribution automation and component lifecycles

Primary components long lifecycle, 30-50 years

Secondary components shorter lifecycle, but still quite long (~20 years)

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Laine: Sähkönjakeluverkonkomponenttien pitoajat, 2005 (MSc Thesis)

BackgroundClimate change and EU’s 20-20-20

Reduction of CO2 emissions needed (EU target 20%)

Other EU targets: 20% more renewables, 20% increase in efficiency

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World Energy Outlook 2009, IEA

BackgroundThe market situation and technological advances

Larger players in the distribution business

Somewhat in Finland (regulation limits the size of companies) but even more in other countries

Rapid growth in Far East, reconstruction in developed countries

Strong need to improve processes increase of automation

Technological advances facilitate operating larger networks (ICT)

Regulation emphasizes power quality and security of supply

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BackgroundElectricity demand rising twice as fast as other demand

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China

105% 195%

India

126% 282%

Europe and North America11% 31%

M. East and Africa

73% 131%Growth in primary energy demand

Growth in electricity demand

IEA forecast 2006-30

Adding 1 GW power plant and all related electric grid infrastructureevery week for the next 20 years

New requirements for substation automationAdvanced fault management

Automatic Fault Location, Isolation and power Restoration (FLIR)

First from Network Control Center, soon directly from substations?

Protection divided to smaller zones

Affect of DG to protection

Adaptive protection,recalculation of settings

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New requirements for substation automationEfficient operation of the network, asset management

Demand response - keeping the power balance in the network (load shedding)

Earlier in transmission networks, coming to distribution and low voltage networks too

Asset management

More information from network components needed, pre-processing already in the substation

Substation automation only 1-2% of the asset value of the whole network, but big impact on the efficiency

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Jeromin: Life cycle cost analysis of transmission and distribution networks, 2009, CIRED

New requirements for substation automationFuture-proof technologies, upgradeability

Functional lifecycle getting shorter than physical lifecycle

More frequent upgrades needed

Basic functionality must still remain robust

Testing and verification important

Multi-vendor platforms

Open/standard interfaces

Cyber security

Now between devices, later within one device?

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Johnson et al: Standard platform for integrated soft protection and control, 2010, ISGT

New requirements for substation automationLow life cycle costs

Challenge for the future – how to adapt to future requirements and take full benefit of new technologies/inventions, but still keep overall life cycle costs on low level?

Cost factors

Installation and commission costs

Upgrade and renewal costs

Maintenance and operation costs

Benefit of the increased reliability and efficiency (largest effect in the long run)

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Architecture possibilities and building blocks

Traditionally the protection functionality has been ‘decentralized’ to bay level devices, new possibilities now to centralize functionalityAlso ‘decentralizing’ functionality from network control center

1. Decentralized 2. Centralized 3. Combined

Architecture possibilities and building blocksCentralized protection

Primary time critical protection in bay level devices Advanced and/or backup protection and monitoring in Station Computer

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Architecture possibilities and building blocksIEC 61850 standard

Importance steadily increasing

Now the de-facto standard in substation automation, usage spreading also outside substation

Edition 1 – ‘Substation automation’, Edition 2 – ‘Power utility automation’

Holistic approach

Modeling of devices

Communication

Engineering processes and tools

etc.

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Physical Device

(network address)

Logical Device

(IED1)

LN2 (PTOC)LN1 (XCBR)

Pos Op

gen. qstVal q

Physical Device

Logical Device

(1 to n)

Logical Node

(1 to n)

Data Class

Data

Architecture possibilities and building blocksIEC 61850 standard - modeling

Architecture possibilities and building blocksIEC 61850 standard – horizontal comm. (Goose)

GOOSE

Process Interface Process Interface Process Interface

ProtectionControlControl &Protection ProtectionControl

Switch

GOOSE

Process Interface Process Interface Process Interface

ProtectionControlControl &Protection ProtectionControl

Switch

More inputs / outputs without additional hardwareAutomatic supervisionHigh performanceFlexibility and expandability

Architecture possibilities and building blocksIEC 61850 standard – process bus

A method for transmitting sampled measurements from transducers such as CTs, VTs, and digital I/OEnables sharing of I/O signals among IEDsEnables dedicated sensor devices (Merging Units)Ethernet based (like Goose)

CTs/VTs

IEC 61850-9-2Process bus

IEC 61850-8-1

Remote

BIOs

SampledValues

IED IED

Architecture possibilities and building blocksIEC 61850 standard – engineering processes

XML based configuration language (SCL, Substation Configuration Language)

Different file types/extensions for different parts of the engineering process

Device level

System level

Visualization

Communication IF

Specifications

Change mgmt

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IEC 61850-6, Edition 2, 2009

Architecture possibilities and building blocksBenefits of centralization

Simplification of bay level devices maintain long lifecycle and stable operation with most critical functions

Easy to take new advanced and value added functionality into use in station level

Maintain life cycle costs on good level

Standard access to process data

Multi-vendor platforms

Research collaboration

New functions utilizingstation level measurements

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Valtari: Increasing Cost-Efficiency of Substation Automation Systems by Centralised Protection Functions, 2009, CIRED

Architecture possibilities and building blocksRe-allocating substation functionality

When it is possible to divide functionality to both bay level and station level devices, how should this be done?

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Critical functions Value-added functionsCritical functions Value-added functions

Unit level mandatory functions

Unit level optional functions

Station level optional functions

Station level mandatory functions

Location

Location

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Architecture possibilities and building blocksRe-allocating substation functionality - communication

If the functionality requires communication, a station levelimplementation would be beneficial

Protection functionality suitable for the station levelAdvanced directional earth-fault and overcurrent protectionBusbar protection based on blockings

Control functionality suitable for the station levelInterlocking

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Architecture possibilities and building blocksRe-allocating substation functionality – response time

If the functionality requires fast response times, it shouldreside close to the process

Fast response time functionsProtection against faults with high fault current magnitude (overcurrent, earth-fault, differential)Control: circuit breaker operationSelf-supervision: breaker failure

Slow response time functionsProtection: overload, phase discontinuityControl: disconnector operation, slow-speed auto-reclosureMonitoring: circuit breaker condition, PQ, disturbance recorderSupervision: IED self-supervision, CT/VT circuit supervision

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Architecture possibilities and building blocksRe-allocating substation functionality - utilization

Functions with high utilization frequencyshould remain on the unit level

Most common faults from outage statisticsFunctional specifications of low end P&C IEDsCommon, ‘widespread’ functions should remain on the unit level

Protection: overcurrent and earth-faultControl: circuit breaker operationMonitoring: event logsSupervision: IED self-supervision

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Architecture possibilities and building blocksRe-allocating substation functionality - stability

Self-healing networks: fault location, post-fault energy restoration, dynamic reconfiguration of network topologyCondition monitoring and asset managementProtection against faults with low fault current magnitude, e.g. HIFProtection adaptation to active resources (DG, EV, energy storages)

Functions where updates are expected in the near futureshould be moved to the station level

Many active research topicsFast utilization of new findings is cheaper and easier on the station levelChanging, ‘immature’ functions should be implemented on the station level

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Summary

CO2 emissions need to be reduced, although electrical energy demand is expected to grow

Efficiency and level of automation needs to be improved

New requirements for substation automation needs to be fulfilled, but the lifecycle costs must be kept on good level

Physical lifetime of devices must stay long, although “functional lifecycle” is expected to get shorter

New technologies and architectures needed for substation automation

Centralization of substation functionality possible the futureIEC 61850 standard allows standard interfaces between devices and systemsEthernet and PC technologies coming to substation automation

Utilizing station level data processing makes new categorization of substation automation functionality possible

Maintain long lifecycle of bay level devices, new features updated to station PC

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