Equipment for Feeder Automation
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Transcript of 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
Customer ReportsOutage
FieldCrews
On-Scene
Travel Time
FaultLocated
Fault Investigation& Patrol Time
Power Restoredto Customers onHealthy Sections
of Feeder
Time to PerformManual Switching Repair Time
Feeder Back toNormal
5 10minutes
15 30minutes
15 20minutes
10 - 15minutes
45 75minutes
FaultOccurs
Feeder Back toNormal
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
Customer ReportsOutage
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
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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
Spread Spectrum Radio
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
Spread Spectrum Radio
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