equipment for feeder automation

8/12/2019 Equipment for Feeder Automation

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K E M A , I N C .

Equipment for Feeder

AutomationRecent Trends in Feeder Automation Seminar

IEEE PES Miami Chapter Miami, FloridaJune 2, 2005

John M cDonald [email protected]

KEMA, Inc .


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IntroductionDistribution Feeder Automation is the monitoringand control of devices located out on the feedersthemselves

Line reclosers

Load break switchesSectionalizersCapacitor banks

Line regulators


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Main Feeder Automation Applications

Automated Feeder SwitchingVolt/VAR Management (Discussed in nextSeminar Module)


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Automated Feeder Switching

Monitoring and control of electricallyoperable switches located outside thesubstation fence

Automated feeder switching usuallyinvolves remote control from a centralizedlocation (I.e., control center)

Operation can be fully automatic, with nomanual intervention


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Primary Application FISR

Fault Location , Isolation, and ServiceRestorationUse of automated feeder switching to:

Detect feeder faultsDetermine the fault location (between 2switches)Isolate the faulted section of the feeder (between

2 feeder switches)Restore service to healthy portions of thefeeder


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Fault Location, Isolation, & Service Restoration (FISR)

When a permanent fault occurs, customers on healthy sections

of the feeder may experience a lengthy outage

FISR provides the means to restore service to some customersbefore field crews arrive on the sceneOverall Objective:

Reduce outage duration for customers on unfaulted (healthy) sections

of the feeder

FaultOccurs

Customer ReportsOutage

FieldCrews

On-Scene

Travel Time

FaultLocated

Fault Investigation& Patrol Time

Power Restoredto Customers onHealthy Sections

of Feeder Time to Perform

Manual Switching Repair Time

Feeder Back toNormal

5 10minutes

15 30minutes

15 20minutes

10- 15minutes

45 75minutes


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Fault Location, Isolation, & Service Restoration (FISR)Fault

Occurs


FieldCrews

On-Scene

Travel Time

FaultLocated

Fault Investigation& Patrol Time

Power Restoredto Customers onHealthy Sections

of Feeder

Time to PerformManual Switching Repair Time


5 10minutes

15 30minutes

15 20minutes

10 - 15minutes

45 75minutes

FaultOccurs


Power Restored

to Customers onHealthy Sections

of Feeder

Travel Time

15 30minutes

1 - 4Hours

Repair Time

1 - 4Hours

1 to 5 minutes

5 - 10minutes

PatrolTime


5 10minutes


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FISR How It Works


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FISR How It Works


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FISR How It Works


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FISR How It Works


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FISR How It Works


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FISR How It Works


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Reliability Improvement Benefit

Actual experience for one KEMA Client:63% SAIDI (outage duration)improvement56% SAIFI (outage frequency)improvement

FISR compares favorably with otherreliability improvement measures in bangfor the buck and overall effectiveness


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Other Uses of Automated SwitchesLoad Shedding

Can shed one section of the feeder if necessaryFeeder Reconfiguration

Use switches to balance load between feeders

Cold Load PickupCan pick up feeder load one section at a time

Intelligent Substation Bus Transfer

Transfer load to another substation followingtransformer failure (Substation automationapplication)


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System Components

Distribution SCADA system (if necessary)Remote controlledfeeder switches (loadbreak, recloser, sectionalizer, etc.) - RCS

Normally-closed line switches Normally-open tie switches

Feeder RTU or Controller Fault detector unit or current sensor

Two-way communication facilities (Sp.Spectrum

MAS


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Remote Controlled SwitchesIntegrated Load Break Switch

Joslyn Vacuum Switch

S&C Omni Rupter

G&W SF6 Switch

Line Recloser

Cooper recloser


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Non Integrated Load Break Switches(Retrofit Motor Operators)


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Feeder Remote Terminal Unit

DAQ Polaris

GE Harris DART

Metso Polecat


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Fault DetectorsDetermines that a fault has occurred

downstream (further from the substation)Must be able to identify the fault before itscleared by fault interrupting devices (a fewcycles)System must capture this information for furtherprocessingMust be able to detect all kinds of faults

Phase faultsGround faults current may be less than normalload must use residual current


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Current & Voltage SensorsSensorsMeasure single/three phase line currents and voltages

and reports these measurements to local controller orRTU Accuracy at least + or - 3%Suitable for measuring fault currentMay be incorporated in the switchMust detect fault before its cleared

Lindsey CurrentSensor Fisher Pierce Line

Post Sensor


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Fault IndicatorsFault Indicators

Clamp on style

Current inrush restraintFault settingsBi-directionalDetect fault before clearing

Reset conditions Time Restoration of voltage or current

Output signal to feeder RTU Radio signal Fiber optic/metallic cable

Local indicator visible from groundlevel

Fisher Pierce

Edison Controls FCI


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Pictures of Fault Indicators


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Radio Transmitter Style Fault Indicator


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Communication FacilitiesSystem requires reliable 2-way communicationfacilities to feeder locationsCommon approaches:

Licensed UHF MAS radioUnlicensed Spread spectrum radio (PTP, MAS,store-and-forward network, Ethernet radio)Cellular telephone (CDPD, 3G cellular)Commercial services (Cellnet, Telemetrics, etc.)


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Hockey Puckantenna for padmounts


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Store and Forward Network Radio


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Use of Optical Fiber Increasing interest in using Optical Fiber tohandle communications with feederswitchesMunicipal utilities installing fiber for cabletelevision and other applications want toexploit this for DAFiber capacity probably overkill for forfeeder switching application but if itsavailable, use it!


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Control PanelsOpen/Close Pushbuttons

Switch status (open/closed) indicators Alarm indicators

Local/remote switchOperations counter


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Switch Power SupplyPower source

dedicated voltage transformer connect to local secondary circuit

Backup Power SupplyProvides ability to operate switch whenassociated feeder is deadShould specify a required number ofoperations with the power off (biggestpower drain is radio transmitter)

Maintenance free rechargeable batterypacksTemperature compensated battery charger Self monitoring capability


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Feeder Automation CategoriesMANUAL

No automatic control System delivers information (recommendations) to Dispatcher Dispatcher executes recommended actions

Pros

Simpler than fully automatic Good starter approach until confidence is built up

Cons Takes longer to restore service (3 5 minutes)

Communication time (both ways) Dispatcher decision time

Difficult for dispatcher to manage many switches during emergenciesinvolving multiple disturbances


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Feeder Automation CategoriesSEMI-AUTOMATIC

Mix of automatic and supervised control Example

FA system automatically isolates fault and performs upstreamrestoration

Dispatcher supervises downstream restoration activities based on FAsystem recommendations

Pros Simpler than fully automatic Natural progression from Manual approach Where most utilities end up Upstream customers restored in less than 1 minute

Cons Takes longer to restore downstream service (3 5 minutes) Difficult for dispatcher to manage many switches during emergencies involving

multiple disturbances


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Feeder Automation Categories

FULLY AUTOMATIC All fault isolation and restoration activities performed

automatically No dispatcher intervention

Pros Possible to restore all service in less than one minute Less burden on Dispatcher to manage the switching

activities Cons

Most complex approach Acceptance difficulties

Ranges from Why not? to Over my dead body


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Feeder Automation Architecture

Standalone Automatic SwitchesReclosers, sectionalizers

Centralized SystemSwitches controlled by central DMS/SCADA

Substation Centered ApproachSubstation unit controls switches on associatedfeeders

Peer to Peer ArrangementGroups of switches communicate to determineappropriate switching actions


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System controlled bycentral SCADA

Acquire data from fielddevices

Process data in SCADAsystemIssue supervisorycontrol commands

Comm. Tower Workstation

Centralized Feeder Automation

Can be manual, semi-automatic,or fully-automatic

K E M A I N C


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Centralized Feeder Automation

Conceptual Block Diagram

SCADA Server

Basic SCADA Functionality

Feeder Automation Appl icati on Server

Feeder ModelsDistribution Power Flow

Load Estimator Topology Processor

FLISR Application SoftwareSwitch Order Management

Substation andFeeder

Devices

Fault indicator status,currents, voltages

Device ControlCommands

GeogaphicInformation

System (GIS)

Real-TimeData

Feeder equipment data,

topologyinformation

Dispatcher Console

Equipment statusand loading

Switching Actions

Central SCADASystem

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ACS Feeder Automation

K E M A I N C


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Some Vendors That Use theCentralized FA Approach

Advanced Control Systems (ACS)

Areva (formerly Alstom)SNC Lavalin ECS (SLECS)Survalent (former Quindar)

SiemensTelvent-Abengoa (formerly Metso)

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Central Scheme Pros & ConsPros

Operators retain controlOperators are always informedConsiderably more operating flexibility

Fewer restrictions (e.g., number of switches controlled) Better ability to handle abnormal situations

No unnecessary switching Additional functionality possible

Non-outage switching Feeder load balancing

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Central Scheme Pros & ConsCons

Requires a distribution SCADA systemRequires an extensive communicationinfrastructure

Requires electrical models updated via GIS

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Substation Centered Approach

Comm. Tower

Local HMI

RTU/PLC

SCADA EMS

Substation

O P T I O N A L

System controlled bySubstation PLC or RTU

Acquire data from fielddevicesProcess data in substationIssue supervisory controlcommands as needed tofield devices

Can be manual, semi-automatic, or fully-automatic

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GE Feeder Automation Scheme

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Substation Centered Vendors

General Electric

Novatech

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Substation Centered Pros/Cons

Pros- Fairly easy to set up and maintain- Doesnt require electrical feeder models- Doesnt require central SCADA- Lowest cost alternative

- Cons- Difficulty in handling complex situations

- Heavily loaded feeders where load must be split up- Limited number of switches controlled- Requires substation feeder communications

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Peer-to-Peer ArrangementNetwork of DistributedControllers

Acquire local data via localsensors Acquire remote data viapeer-to-peercommunications with othercontrollersProcess data locally

Open/close associated switchas neededPrimarily intended for fully-automatic operation

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Peer-to-Peer ArrangementNo SCADA central station required

Most implementations haveremote monitoring

Switching decisions madeautomatically prior to lockoutbased on:

Extended loss of voltageThrough fault current

Prefault loading

Dispatcher User Interface

O p t io na l

Co n t ro l Ce n te r

I n te r face

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S&CIntelliTEAMIOriginal IntelliTEAM Capabilies :

Teams can have up to seven switchesOnly two sources of power allowedTeams must contain only one open switchNo switch can be in multiple teams

Not adaptable to multiple source topology

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S&CIntelliTEAMIIIntelliTEAM II Capabilities:

A team is now a line segment bounded by switchesTeams can include up to 8 switchesTeams can have up to 8 separate sources of supplySwitches canbelong to multiple teams

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Peer to Peer Pros and ConsPros

Doesnt require: Central SCADA system Feeder models supported by GIS interface Extensive communications infrastructure

Speed of operation (30 seconds or less)

Costs less than central approachPrimary application is FISR, but not limited to this

Can be fully functional feeder SCADA system

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S&C Electric

Jungle Mux

Terminal Server

D20

Spread Spectrum Radio

Substation

S&C 5800

SwitchController

S&C 5800

SwitchController

S&C 5800

Switch

Controller

Jungle Mux

Terminal Server

D20


Substation

S&C 5800

SwitchController

S&C 5800

SwitchController

S&C 5800

SwitchController

Survalent Master Proxy Server

Jungle Mux

Firewall

Logic Module

Jungle Mux

Terminal Server

D20


Substation

S&C 5800

SwitchController

S&C5800

SwitchController

Control Center

S&C 5800

SwitchController

Broadband Fibreoptic Network

S ys tem Architec ture

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Peer to Peer Pros and ConsConsLack of operator visibility and control

Can add SCADA interface (most utilities do!)Communication difficulties

Peer-to-peer communications among pole top units can be achallenge!

Single vendor solutionCosts more than substation centered approachSome unnecessary switching involved

Switches in a team open regardless of fault location Then close back in as necessary May fail to close? Extra mechanical operations?

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Feeder Automation Training Simulator


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Tradeoff: Permanent vs. MomentaryOutagesDefinitions:

Permanent: Duration > thresholdMomentary: Duration < threshold

Use of FISR will:Improve permanent outage statistics

SAIDI, SAIFI, CAIDI

Make momentary outage statistics worse MAIFI

Most utilities are willing to accept this tradeoff!

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Limitations on Transferring Load to Adjacent Feeders

It is often difficult to transfer all the healthy

load to adjacent feeders without causingoverloads and/or voltage problems

Especially true during peak load period

May need to split load being transferred toalternative sources

May require additional automated switches

to accomplish FISR objectives at certaintimes of the day

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Diminishing Returns Additional reliability improvement benefit declinesdramatically as more switches are added

Reliability Improvement vs. Cost

0

500

1000

1500

20002500

3000

0 20000 40000 60000 80000 100000

Cost ($)

C u s t

O u

t a g e

M i n u

t e s

I m p r o v e m e n t

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Importance of Switch Placement

Predicted reliability improvement varies widelywith switch placement strategy

Variation observed for sample case:SAIDI - 22%SAIFI - 31%MAIFI - 23%

Small change in placement (a few hundred feet)produced a 5% change in SAIDI!

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First Segment Fault Detection Always an issue!System requires a lockout for fault signal fromthe substation to trigger feeder switchingactivities

Fault has occurredFeeder protection has completed its automaticreclosing cycle

Works best if a protective relay IED is available

in the substation and can be interfaced to theFISR system

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Non-Fault vs Fault TrippingSystem must be ale to distinguish between non faultand fault tripping of the substation circuitbreaker/recloser

Fault Tripping A feeder fault has occurred or supply has been lostdue to a transmission substation faultFISR should attempt to restore service

Non-Fault TrippingSubstation CB tripped for reasons other than afeeder fault

Manual operation by switching personnel or supervisorycontrol from the control center Underfrequency/undervoltage load shedding

FISR should not attempt to restore service

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Safety IssuesSafety for workers and general public must notbe compromised!!!

Operating practices and procedures must bereviewed and modified if necessary to addresspresence of automatic switchgear

Safety related recommendations:Requirement for visible gapNo automatic closures after two minutes haveelapsed following the initial faultSystem disabled during maintenance (live line)work

equipment for feeder automation

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