substation automation and smart grid

8/3/2019 Substation Automation and Smart Grid

1/20

Substation Automationand Smart Grid

GEEnergy

John D. McDonald, P.E.

POWERING POTENTIA L

The Smart Grid

GM, T&D Marketing

IEEE PES Past PresidentIEEE Division VII DirectorIEEE Fellow

Current Situation

Current IED Penetration

10%

20%

30%

40%

50%

60%

2/GE /

A little more than half of existingT&D substations are equipped withIEDs

0%

No IEDs IEDs

Source: The World Market for Substation Automation and Integration Programs

in Electric Utilities: 2005-2007; Newton-Evans Research Company, Inc.

Current Situation (continued)

IED Level of Integration

10%

20%

30%

40%

50%

60%

3/GE /

55% of IED substations have no integration(29% of total subs)

45% of IED substations have some integration(24% of total)

0%

IEDs - No integration IEDs with some level of integration and

automation


2/20

Plans for Retrofit Substations

Retroft Substations

10%

20%

30%

40%

50%

60%

4/GE /

97% of retrofit T&D substations will haveIEDs

42% of retrofit T&D substations includeIED integration and automation

0%

No IEDs IEDs - No Integration IEDs with some level of

integration

Plans for New Substations

Plans for New Substations

10%

20%

30%

40%

50%

60%

70%

80%

90%

5/GE /

97% of T&D substations will have IEDs 85% of T&D substations will include IED

integration and automation

0%

No IEDs IEDs - No Integrat ion IEDs with some level of

integration

Why Needed? Why Now?

DEREGULATION & COMPETITIONDeregulation driving actions of

most utilitiesMajor driving forces:

Improved power quality and

service reliability

6/GE /

New energy related servicesand business areas

Lower cost of service Information needed for

improved decision makingSA: A proactive response to these

forces


3/20


DEVELOPMENT OF IEDsRapid development and deployment of

Intelligent Electronic Devices (IEDs)

Protective relays Meters Equipment condition monitors

IEDs have become an integral part of

7/GE /

Substation Automation systemsTechnological developments have made SA

Systems less expensive and more powerful

RTU

Direct-

Wired

I/O

Data

Concentrator

IED IED IED

LAN


ENTERPRISE-WIDE INTEREST ININFORMATION FROM IEDsOperational Data

Amps, volts, watts, VARs, fault location,switchgear status

Non-Operational Data E ui ment condition

8/GE /

Fault event and power quality data

(waveforms)Persons working outside the control room

want access for improved decision making

SA Platform

EMS/DMS

Corporate

Data Warehouse


IMPLEMENTATION AND ACCEPTANCE OFSTANDARDSConfusion over industry communication

standards is diminishingInternational standards have become reality

9/GE /

Standards based implementation projectsunderway at many electric utilities Widespread use ofde facto standards for IED

communications (DNP3, Modbus. Modbus+) Some use ofde jure standards

(UCA2/IEC61850)


4/20

eve ene s

Construction Cost Savings

Electromechanical Devices IEDs

Required functionality bundled in fewercomponents (21, 50/51, 79,, metering,etc)

One IED may replace many E-Mdevices

11/GE /

WM+

AM A VM

VarM+

PF+

+ + +

WH

+

VarH

+

50/51N+

50/51A+

50/51B+

50/51C+

AS+

VS+

52CS

G R

TS+

+

46

WM+

AM

VarM+

PF+

+

WH

+

VarH

+

50/51N+

50/51A+

50/51B+

50/51C+

AS+

52CS

G R

TS+

+

79

WM+

AM

VarM+

PF+

+

WH

+

VarH

+

50/51N+

50/51A+

50/51B+

50/51C+

AS+

52CS

G R

TS+

+

79

AM+

50/51A+

50/51B+

50/51C+

AS+

86+

52CS

G R

TS+

+

50/51G+

++

87TA

+

46

W

87TB

87TC

Transformer T1 Main Bkr M1 Feeder Bkr F1 Feeder Bkr F2

+

TS+

+

TPU

+

+

DPU

+

DPU

F1

+

DPU

F2

+ + +

+ +


Reduction in Physical Complexity Less inter-device wiring Fewer unique devices to inventory Some traditional devices eliminated

altogether

12/GE /


5/20


Relay/control house size (newconstruction only)

Design & construction labor andmaterials

13/GE /

Integrated Protection Functions

Objective: Incorporate protectionfunctions in the SA SystemBasic protection units (IEDs)

exchange current/voltage data via

hi h s eed LAN

15/GE /

Relay trip signals exchanged over

LAN

Bus

Diff

RelayHardwired Hardwired

AC AC

DC DC

Traditional

(Electromechanical)

Approach


6/20

Integrated Protection Functions

Objective: Incorporate protectionfunctions in the SA System

Basic protection units (IEDs)exchange current/voltage data viahi h s eed LAN

16/GE /

Relay trip signals exchanged over

LAN

Relay

IED

AC

DC DC

Integrated IED

Approach

Relay

IED

Local Area

Network

Current/Voltage meas;

Status/Trip signals

115kVSource

Integrated Protection Breaker Failure

17/GE /

69kV Bus

Source atRemote End

115kV

Source


18/GE /

69kV Bus

Source at

Remote End

Fault


7/20

115kVSource


19/GE /

69kV Bus

Source atRemote End

ProtRelayIED

OC

115kVSource


20/GE /

69kV Bus

Source atRemote End

Prot

RelayIED

OC

115kVSource


21/GE /

69kV Bus

Source atRemote End

ProtRelayIED

OC

BreakerFailure


8/20

115kVSource


22/GE /

69kV Bus

Source atRemote End

ProtRelayIED

OC

Breaker

Failure

BF

Hardwired

Hardwired

115kVSource


23/GE /

69kV Bus

Source atRemote End

Prot

RelayIED

OC

Breaker

Failure

BF

Hardwired

Hardwired

115kVSource


24/GE /

69kV Bus

Source atRemote End

ProtRelayIED

OC

BreakerFailure


9/20

115kVSource

Protl


25/GE /

69kV Bus

ProtRelayIED

OC

RelayIED

ProtRelayIED

Substation LAN

115kVSource

ProtRelayIED


26/GE /

69kV Bus

ProtRelayIED

OC

I

ProtRelayIED

Substation LAN

GOOSE Messages

115kVSource

Prot

RelayIED


27/GE /

69kV Bus

ProtRelayIED

OC

I

ProtRelayIED

Substation LAN

GOOSE Messages


10/20

Automation Functions

Nature of the problemDistribution substations often tapped

off supply line without high sidebreaker or high side protection

Considerable load may be out of

Automatic Load Restoration:Supply Line Sectionalizing

29/GE /

service until field crews arrive onscene

ObjectivesIdentify faulted section of supply lineIsolate faulted sectionRestore supply to substations fed off

unfaulted section of supply line

Supply Line Sectionalizing

30/GE /

SA

System


11/20


Permanent

Fault Occurs

31/GE /

SA

System


Line

Protection

Operates

32/GE /

SA

System


33/GE /

Line Protection

Reports Fault

Location

SA

System


12/20


34/GE /

SA System Opens

Appropriate MOD

SA

System


35/GE /

SA System Sends

Reclose Signal

SA

System

Nature of ProblemWhen a transformer failure occurs,

simple bus failover schemetransfers load to healthy

transformer

Automatic Load Restoration:Intelligent Bus Failover

36/GE /

mp e a over sc eme mayoverload healthy transformer,especially during peak load

Some schemes have been disabledbecause of this

Substation firm capacity limited byamount of load that can be carried ifa transformer fault occurs


13/20

ObjectivesTransfer as much load as possible

to 2nd substation transformer

Automatic Load Restoration:Intelligent Bus Failover

37/GE /

,to alternate substation

Shed portion of load if necessary

Intelligent Bus Failover:

How It Works

38/GE /

Transformer

Fault

Intelligent Bus Failover:How It Works

39/GE /


14/20

Transformer

Fault

Intelligent Bus Failover:

How It Works

40/GE /

Trf

Protection


41/GE /


42/GE /

Bus Transfer

Scheme

Operates


15/20


43/GE /

Shed Load

If Necessary

To Adjacent

Substation


44/GE /

Restore Load

Using Feeder

Automation

To Adjacent

Substation

Enter riseApplicationFunctions


16/20


17/20


18/20

Disturbance Analysis

Exploit Inherent Capabilities ofIEDs

Sequence of Event reportingDigital Fault Recorder (DFR)Fault Location

52/GE /

Disturbance Data from

relay IED

Computer

Engineers Desktop

Intelligent Alarm Processing

Prioritize alarm informationEliminate duplicate & nuisance alarmsRoute alarm info to appropriate partyExpert alarm processing

provides more informative and useful

53/GE /

alarm messages

Phase A Phase Overcurrent Alarm

Phase B Overcurrent Alarm

Ground Overcurrent alarm

CB change of state

Loss of voltage

Etc..

Feeder Fault A-B-GAlarm

Filter

Power Quality Monitoring

SA System and IEDs able to detectpower quality events and report thefollowing information: Harmonic content of the voltage

waveform

Total harmonic distortion

54/GE /

Power Quality Info from IEDs

Computer

Engineers Desktop


19/20

Real-Time Equipment Rating

Base equipment ratings onactual conditions rather thanconservative assumptions

Squeeze more capacity out ofexisting equipment

Exam le:Transformer Hot S ot

55/GE /

Monitoring Monitor the true winding hot spot

temperature

Derive loadability from the results

5 - 10% additional loading can be

achieved

Continuous On-lineDiagnosis of SSEquipment (HVbreakers, Transformers)

Equipment Condition Monitoring

56/GE /

Support reliability centered

maintenanceFind/fix problems earlierAvoid forced

(unscheduled) outages

Reduce maintenance costs

Equipment Monitoring Devices

Dissolved Gas in Oil Monitors/Samples

Moisture Detectors

Load Tap Changer Monitors

Partial Discharge/Acoustic Monitors

57/GE /

Bushing Monitors

Circuit Breaker Monitors (GIS and OCB)

Battery Monitors

Expert System Analyzers

Protective Relay IEDs (I2t, Breaker timing)


20/20

Role of SAMonitor specialized

sensorsPerform expert system


58/GE /

Inform engineers ordispatchers of possibleproblems

Supply non-operationaldata


Triggers, Alerts

SubstationMaintenance

Office

Traditional approach:

59/GE /

Telephone

MaintenanceManagement

System

ConditionMonitoring

Sensor

Modem


SA approach Use Non-Operational Data

Path:

Workstat ion Workstat ion Workstation

Modem Data

Firewall

Engineering PC

Data

FirewallRouter

OperationalData

60/GE /

Server Server

IED IED IED

Radio tower

DataConcentrator

Local HMI

IED

TCP/IPCorp WAN

Router

Server

DataWarehouse

Non-Operational

Data

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