05 substation automation and smart grid.ppt - ieee automation... · substation automation and smart...

1

Substation Automation and Smart Grid

GEEnergy

John D. McDonald, P.E.GM T&D M k i

POWE RI NG P O TE N TIA L

The Smart Grid

GM, T&D Marketing

IEEE PES Past PresidentIEEE Division VII DirectorIEEE Fellow

Current SituationCurrent IED Penetration

10%

20%

30%

40%

50%

60%

2 /GE /

• A little more than half of existing T&D substations are equipped with IEDs

0%No IEDs IEDs

Source: “The World Market for Substation Automation and Integration Programsin Electric Utilities: 2005-2007”; Newton-Evans Research Company, Inc.

Current Situation (continued)

IED Level of Integration

0%

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

Plans for “Retrofit” Substations

Retroft Substations

10%

20%

30%

40%

50%

60%

4 /GE /

• 97% of retrofit T&D substations will have IEDs

• 42% of retrofit T&D substations include IED 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 Integration IEDs with some level of

integration

Why Needed? Why Now?

• DEREGULATION & COMPETITION– Deregulation driving actions of

most utilities– Major driving forces:

• Improved power quality and service reliability

6 /GE /

• New energy related services and business areas

• Lower cost of service• Information needed for

improved decision making– SA: A proactive response to these

forces

3

Why Needed? Why Now?• DEVELOPMENT OF IEDs

– Rapid development and deployment of Intelligent Electronic Devices (IEDs)• Protective relays• Meters• Equipment condition monitors

– IEDs have become an integral part of

7 /GE /

g pSubstation Automation systems

– Technological developments have made SA Systems less expensive and more powerful

RTUDirect-

Wired

I/O

DataConcentrator

IED IED IED

LAN

Why Needed? Why Now?• ENTERPRISE-WIDE INTEREST IN

INFORMATION FROM IEDs– “Operational” Data

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

– “Non-Operational” Data• Equipment condition

8 /GE /

Equipment condition • Fault event and power quality data

(waveforms)– Persons working outside the control room

want access for improved decision making

SA Platform

EMS/DMS

CorporateData Warehouse

Why Needed? Why Now?• IMPLEMENTATION AND ACCEPTANCE OF

STANDARDS– Confusion over industry communication

standards is diminishing– International standards have become reality

UCA2 IEC61850

9 /GE /

– Standards based implementation projects underway at many electric utilities• Widespread use of de facto standards for IED

communications (DNP3, Modbus. Modbus+)• Some use of de jure standards

(UCA2/IEC61850)

UCA2 IEC61850

4

IED L l B fitIED Level Benefits

Construction Cost Savings

Electromechanical Devices IEDs

• Required functionality bundled in fewer components (21, 50/51, 79,…, metering, etc)

• One IED may replace many E-M devices

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

+ + +

+ +

IEDs


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

altogether

12 /GE /

5


• Relay/control house size (new construction only)

• Design & construction labor and materials

13 /GE /

Integration Level BenefitsIntegration Level Benefits

Integrated Protection Functions

• Objective: Incorporate protection functions in the SA System– Basic protection units (IEDs)

exchange current/voltage data via high speed LAN

15 /GE /

high speed LAN– Relay trip signals exchanged over

LANBusDiff

RelayHardwired Hardwired

AC AC

DC DC

Traditional (Electromechanical) Approach

6

Integrated Protection Functions

• Objective: Incorporate protection functions in the SA System– Basic protection units (IEDs)

exchange current/voltage data via high speed LAN

16 /GE /

high speed LAN– Relay trip signals exchanged over

LANRelayIED

AC

DC DC

Integrated IED Approach

RelayIED

Local Area Network

Current/Voltage meas; Status/Trip signals

115kVSource

Integrated Protection – Breaker Failure

17 /GE /

69kV Bus

Source atRemote End

115kVSource


18 /GE /

69kV Bus

Source atRemote End

Fault

7

115kVSource


19 /GE /

69kV Bus

Source atRemote End

ProtRelayIED

OC

115kVSource


20 /GE /

69kV Bus

Source atRemote End

ProtRelayIED

OC

115kVSource


21 /GE /

69kV Bus

Source atRemote End

ProtRelayIED

OC

BreakerFailure

8

115kVSource


22 /GE /

69kV Bus

Source atRemote End

ProtRelayIED

OC

BreakerFailure

BF

Hardwired

Hardwired

115kVSource


23 /GE /

69kV Bus

Source atRemote End

ProtRelayIED

OC

BreakerFailure

BF

Hardwired

Hardwired

115kVSource


24 /GE /

69kV Bus

Source atRemote End

ProtRelayIED

OC

BreakerFailure

9

115kVSource

ProtR l


25 /GE /

69kV Bus

ProtRelayIED

OC

RelayIED

ProtRelayIED

Substation LAN

115kVSource

ProtRelayIED


26 /GE /

69kV Bus

ProtRelayIED

OC

IED

ProtRelayIED

Substation LAN

GOOSE Messages

115kVSource

ProtRelayIED


27 /GE /

69kV Bus

ProtRelayIED

OC

IED

ProtRelayIED

Substation LAN

GOOSE Messages

10

Automation Functions

• Nature of the problem– Distribution substations often tapped

off supply line without high side breaker or high side protection

– Considerable load may be out of

Automatic Load Restoration:Supply Line Sectionalizing

29 /GE /

yservice until field crews arrive on scene

• Objectives– Identify faulted section of supply line– Isolate faulted section– Restore supply to substations fed off

unfaulted section of supply line

Supply Line Sectionalizing

30 /GE /

SASystem

11


PermanentFault Occurs

31 /GE /

SASystem


LineProtectionOperates

32 /GE /

SASystem


33 /GE /

Line ProtectionReports Fault

Location

SASystem

12


34 /GE /

SA System OpensAppropriate MOD

SASystem


35 /GE /

SA System Sends Reclose Signal

SASystem

• Nature of Problem– When a transformer failure occurs,

“simple” bus failover scheme transfers load to healthy transformer“Si l ” f il h

Automatic Load Restoration:“Intelligent” Bus Failover

36 /GE /

– “Simple” failover scheme may overload healthy transformer, especially during peak load

– Some schemes have been disabled because of this

– Substation firm capacity limited by amount of load that can be carried if a transformer fault occurs

13

• Objectives– Transfer as much load as possible

to 2nd substation transformerIf necessary transfer portion of load

Automatic Load Restoration:“Intelligent” Bus Failover

37 /GE /

– If necessary, transfer portion of load to alternate substation

– Shed portion of load if necessary

“Intelligent” Bus Failover:How It Works

38 /GE /

TransformerFault

Occurs


39 /GE /

Occurs

14

TransformerFault

Occurs


40 /GE /

Occurs

TrfProtectionOperates


41 /GE /

Operates


42 /GE /

Bus TransferScheme

Operates

15


43 /GE /

Shed LoadIf Necessary

To Adjacent

Substation


44 /GE /

Restore LoadUsing FeederAutomation

To Adjacent

Substation

Enterprise pApplication Functions

16

SCADA Data Path (Operational Data)

Workstation Workstation Workstation

Modem Data

46 /GE /

Server Server

IED IED IED

Radio tower

DataConcentrator

Local HMI

IED



Modem DataFirewall

Engineering PC

Data

47 /GE /

Server Server

IED IED IED

Radio tower

DataConcentrator

Local HMI

IED

Server

DataWarehouse



Modem DataFirewall

Engineering PC

Data

Operational Data

48 /GE /

Server Server

IED IED IED

Radio tower

DataConcentrator

Local HMI

IED

Server

DataWarehouse

17



Modem DataFirewall

Engineering PC

Data

Operational Data

49 /GE /

Server Server

IED IED IED

Radio tower

DataConcentrator

Local HMI

IED

Server

DataWarehouse

SCADA Data Path (Non-Operational Data)


Modem DataFirewall

Engineering PC

DataFirewallRouter

Operational Data

50 /GE /

Server Server

IED IED IED

Radio tower

DataConcentrator

Local HMI

IED

TCP/IP Corp WAN

Router

Server

DataWarehouse

SCADA Data Path (Non-Operational Data)


Modem DataFirewall

Engineering PC

DataFirewallRouter

Operational Data

51 /GE /

Server Server

IED IED IED

Radio tower

DataConcentrator

Local HMI

IED

TCP/IP Corp WAN

Router

Server

DataWarehouseNon-

OperationalData

18

Disturbance Analysis

Exploit Inherent Capabilities of IEDs

– Sequence of Event reporting– Digital Fault Recorder (DFR)– Fault Location

52 /GE /

Disturbance Data from relay IED

Computer

Engineer’s Desktop

Intelligent Alarm Processing

– Prioritize alarm information– Eliminate duplicate & nuisance alarms– Route alarm info to appropriate party– “Expert” alarm processing

• provides more informative and useful l

53 /GE /

alarm messages

Phase A Phase Overcurrent Alarm Phase B Overcurrent AlarmGround Overcurrent alarmCB change of stateLoss of voltageEtc…..

Feeder Fault A-B-GAlarmFilter

Power Quality Monitoring– SA System and IEDs able to detect

power quality events and report the following information:• Harmonic content of the voltage

waveform• Total harmonic distortion• Oscillographic data (waveforms)

54 /GE /

• Oscillographic data (waveforms)

Power Quality Info from IEDsComputer

Engineer’s Desktop

19

Real-Time Equipment Rating

– Base equipment ratings on actual conditions rather than conservative assumptions

– Squeeze more capacity out of existing equipment

– Example: Transformer “Hot Spot”

55 /GE /

Example: Transformer Hot Spot Monitoring

• Monitor the true winding hot spot temperature

• Derive loadability from the results• 5 - 10% additional loading can be

achieved

• Continuous On-line Diagnosis of SS Equipment (HV breakers, Transformers)

• Main objectives

Equipment Condition Monitoring

56 /GE /

• Main objectives– Support reliability centered

maintenance– Find/fix problems earlier– Avoid 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

• Role of SA– Monitor specialized

sensors– Perform “expert system”

analysis


58 /GE /

analysis– Inform engineers or

dispatchers of possible problems

– Supply “non-operational” data


Triggers, Alerts

SubstationMaintenance

Office

• Traditional approach:

59 /GE /

TelephoneMaintenanceManagement

System

ConditionMonitoring

Sensor

Modem

Equipment Condition Monitoring• SA approach – Use “Non-Operational Data

Path:


Modem DataFirewall

Engineering PC

DataFirewallRouter

Operational Data

60 /GE /

Server Server

IED IED IED

Radio tower

DataConcentrator

Local HMI

IED

TCP/IP Corp WAN

Router

Server

DataWarehouseNon-

OperationalData

05 substation automation and smart grid.ppt - ieee automation... · substation automation and smart...

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