line sensors for distribution automation · ©tav networks, inc. 2017 31. product comparison...

Line Sensors for Distribution Automation: Practical Deployment, Data Collection and Use Cases

TAV Networks, Dayton Power & Light, and Pacific Gas & Electric

UU Course 202 - January 30, 2017Distributech 2017

©TAVNetworks,Inc.2017 1

InstructorsJoe Tavormina

• Comms&SensorsSystems:TAVNetworks,Inc.

Jeff Teuscher

• DistributionOpsManager:DaytonPower&Light

Stan Thompson

• PilotOperations:PacificGas&ElectricCompany

Jared Hafer

• DeploymentProjectManager:PacificGas&ElectricCompany©TAVNetworks,Inc.2017 2

Schedule 08:00 – Introduction to Line Sensors and Use Cases (15 minutes, Joe Tavormina)

08:15 –The Role of Line Sensors in Utility Operations (15 minutes, Jeff Teuscher)

08:30 – Theory and Operation of Line Sensors (30 minutes, Joe Tavormina)

09:00 – Use Case 1: Bracketing Fault Location (30 minutes, Stan Thompson)

09:30- Use Case 2: Calculating Fault Location (30 minutes, Stan Thompson)

10:15 – Break (15 minutes)

10:15 – Use Case 3: Asset Management (15 minutes, Jeff Teuscher)

10:30 – Use Case 4: Power Quality Investigation (15 minutes, Jeff Teuscher)

10:45 – Use Case 5: Vegetation Management (15 minutes, Joe Tavormina)

11:00 – Planning and Executing a Deployment Project (45 minutes, Jared Hafer)

11:45 – Q&A (15 minutes)

12:00 – End


Content• Line Sensors: in Distribution Automation

• Line Sensors: Operations and Communication• Current and Voltage sensing• Power harvesting, consumption, and management• Radio communications

• Deployment: Practical Aspects • Data management in today’s world of growing network security

requirements• Use of Line Sensor data in today’s utility operations environment• Streamlining data presentation for system operators

• Based on real world Line Sensor projects at PG&E and DP&L©TAVNetworks,Inc.2017 4

Purpose• ProvideattendeesabasisforplanningandexecutingLineSensorprojects• ReviewintendedbusinessbenefitsneededtojustifyLineSensorprojects• Discussrisksthatarelikelytobeencounteredduringprojectexecution• Discussintegrationintoexistingutilityoperationalprocessesandapplicationofdatareceivedfromlinesensors

• Sharereal-worldchallengesexperiencedandlessonslearnedinprojectsat:

• PacificGas&ElectricCompanyinCalifornia(PG&E)• DaytonPowerandLight(DP&L)inOhio


Objectives• After taking this course the participant will be familiar with:

• ThepracticaluseanddeploymentofLineSensors• BusinessbenefitsthatcanrealizedusingLineSensors• Sensordatamanagement,theuseofcellularandmeshradionetworks,radiocoverage,andoperationunderlowpowerconditions

• PlanningforbothphysicaldeploymentandITintegration• “Lessonslearned”fromfielddeploymentsatPG&E&DP&L

©TAVNetworks,Inc.2017

• Be ready to mastermind a deployment project:

6

Introduction to Line Sensors and Use CasesJoeTavormina

7

Line Sensor ExamplesOverhead Underground

TollgradeSentientEnergy

Eaton

PG&EExperimentalVoltageSagMonitor

SurfaceOperableVaultInstallation

PadMountInstallationOverheadInstallation

Grid-Sentry©TAVNetworks,Inc.2017 8

UseCasesandBusinessBenefitsUse Case BusinessBenefits

FaultDetection,Location,andRapidRestoration• Readilyidentifiableandimmediatebenefits• DirectimpactonCAIDIandSAIDImetrics• Faultbracketing• High-precisioncalculatedfaultlocation

• Morerapidpowerrestoration• Moreefficientuseofrestorationresources• Improvementsinoutageperformance• Potentialdetectionofhigh-impedancefaults

PowerQualityMonitoring• ImmediateuseasanDistributionPlanningtool• Potentialuseasadynamicfeedbackmechanism

• DatasourceforDMSanddatahistorian

AssetManagement• CostsavingsinOperationsandMaintenance• Inexpensiveformofsubstationautomation

• Situationalawarenessalongextentofdistributionlines

• VerificationofRecloseroperation• VerificationofCapBankintegrity

VegetationManagement• Experimentalatthistime– requiresnewanalytics • Condition-basedvegetationmanagement


Adoption Decision 1: Cellular or Mesh Network?• CellularNetwork(Verizon,AT&T,Sprint,etc.):

• Radiocoverage(reliabilityfromwithinpadmountcover?)• Long-termnetworksupport(2G,3G,4G,LTE,etc.)• Operationalcostforbandwidthconsumption

• MeshNetwork(SSN,Cisco,Itron,etc.900MHz):• Radiocoveragetobattery-backedRadioRelaybackhauldevice• LatencyandTrafficCapacityinamulti-hopmeshnetwork• Capitalcostfornetworkdeployment

• Other:• SatelliteCommunications(“Satcom”)• Wi-Fi


Adoption Decision 2: IT Strategy for Head End?• UseCase

• Setsrequirements

• OperatorInterface• UseofExistingand/orAdditionalGUI?

• DataRepository• DMS,PiHistorian,SCADA,orother?

• DataCenter• In-HouseorHosted?• SecurityMandates

PG&EITDesignforTollgradeLineSensorPilotDeployment©TAVNetworks,Inc.2017 11

The Role of Line Sensors in Utility OperationsJeffTeuscher

12

Sensor Roles on the Distribution System• Faultlocationandmagnituderecording• Reducefieldpatrollingtolocationcausesoflineoutages• Powerqualitydatacanbecapturedandanalyzedtopredictfutureequipmentfailurethroughdatatrending

• Fieldequipmentmonitoring– lowercostalternative• Sensorsprovidemanydatapointsfordistributionsystemtoanalysis• Circuitbalancingtools• EngineeringPlanningtoolsforquickaccesstolineloading• Alertsonreversepowerflows• Voltagesensing


Asset Management Functions• Allowassetstobemonitoredreal-time• Trackequipmentoperationstodecidemaintenancecycles• Powerqualitydatacanbecapturedandanalyzedtopredictfutureequipmentfailurethroughdatatrending

• SensordatacanfeedDistributionManagementSystemsforreal-timemodelingofthedistributionsystem.Allowsforoptimizationoftheutilityassets

• Sensorscanprovidemanydatapointsforassetsystemstoanalyze• Dataiskeytobetteranalyticsandthisleadstobetterassetmanagement


Hydraulic Recloser plus Line Sensor • CostSavingsof$2000perinstallation

• HydraulicRecloser+Sensor=$2500+$1000=$3500• ElectronicRecloser=$5500

• Sensorwillalerttheoperationscenterwhenithasoperatedandwenttolockout

• Sensorwillallowfortrackingnumberofoperationsontherecloser

• Sensorwillprovidereal-timeamperagedatatounderstandloadingontherecloser


Sensors as an alternative to expensive distribution assets

• HydraulicRecloserandSensorvsElectronicRecloser• CircuitMonitoringatSubstationvsRTUandDigitalRelays• PlanningTools– SensorsMonitoringLoadvsLoadLoggerTechnology• MonitorCapacitorGroundforcurrentflow.Signalsablownfuseonthethreephasebank.

• Monitorcircuitbalanceatpointsalongthecircuit.• Potentialtouseforvegetationgrowth.Basedonsmallinterruptionorsmallcurrentfluctuations.

• Faultdetectionandreportingonthedistributionsystem


Sensors as Circuit Monitors at Substations• SubstationsthatdonothaveanRTUinstalledtoday.• Sensorswillbedeployedoneachcircuitleavingthesubstation.• Circuitmonitoringcanbeachievedatmuchreducedcost.SensorsareApproximately$3500percircuitinstalled.

• RTUwithcommunicationsisapproximately$50k- $75kbeforedigitalrelaysareinstalled.

• Sensorallowscircuitloading,alertwhencircuithasoperated,aggregateofcircuitloadsprovidestransformerloading.

• Sensorsaremonitoringonly,whereasRTUprovidescontrolatthesubstation.


Sensors as Planning Tools• Sensors=$1000each– LoadLoggersare$1600each

• Sensorsprovidedatanearreal-timeloaddatatotheengineers

• Sensorsdon’tneedbatteries• LoadLoggersneedtobeinstalledforaperiodoftimeandthenremovedtoretrievethedata

• Loadloggerneedssoftwaretodownloaddata• Sensorsuppliesdatatoutilitysystemofchoice


Theory and Operation of Line SensorsJoeTavormina

19

Line Sensors provide most business benefits for a fraction of the cost

• Easeofinstallation• EaseofintegrationintoADMS,SCADAand/orHistorian• “No”batteriesincluded• Noneedtorolltruckstoreadsubstationloads.Canbecollectedwiththesensors.

• Abilitytocapturefaultcurrentevents.Magnitudeandduration.• Abilitytoprovideconductorlinetemperature– DynamicLinerating.• Monitorneutralcurrentatcapacitorbanks– largecurrentsshowcapacitorhasblownonephaseofthe3Φ bank.


Current Measurement• BasedonRogowskicoil• SplitringpermitsinstallationonDistributionLine

Reference:EEPublishers,July2016,“Rogowskicoilsinsmarttransformer

monitoring”

Reference:Weiku.comTollgradeLightHouseMVCurrentSensor ©TAVNetworks,Inc.2017 21

Voltage Measurement• Directvoltagemeasurementat>12KVisexpensive,andcanposesafetyrisks

• Example:TollgradeMVPowerSensor

• Directvoltagemeasurementontransformersecondarycanserveasaproxy

• Examples:PG&EVSM,QNALineWatch

TollgradeLightHouseMVPowerSensor

QinetiQ-NALineWatch

PG&EVoltageSagMonitor


Line Sensor Data Collection• EventDriven• Periodicmeasurements

• Daily/hourly• Interval• Perphase• Current/EMF(Voltage)

• Other• PhaseIdentification(Automatic?Needsregionalmasterreferenceunit)

• Localreadingsfromfieldmeasurements• Head-endsetting/configuration


CellularorMeshNetworkbackhaul:◦ Verizon,AT&T,Sprint,etc.◦ SSN,Cisco,Itron,etc.(900MHz)

Phaseanglemeasurements:◦ Seevoltageandcurrentwaveformsnotinphase

◦ Takecorrectiveaction(capacitors/inductors)

23

Example of Sensor Data on 4kV Circuit


7 Days24

Configuring Set Points and Alarms• DNP3points/mapping?

• IdentifywhatisdeliveredtoDMS• ONLYfaultdata?(Minimalalerts)• Currentload,phaseimbalance,communicationsstatus,temperature,locationchangesandmoreareallconfigurabletosendalertstoDMS

• (verynoisy/falsepositives)

• Matchingknowntripsettings?• Existingprotectivedevicesettings• Feeder/device/loadspecific• Distributionengineerknowledge

• Outagetimers?• Definesensortimertoallowforprotectivedevicestooperate• Typically~60secondsforrecloserstoattempt3


Communication Performance Factors• RadioNetworkCoverage

• OverheadDistribution• UndergroundDistribution• StatisticalModeling

• PowerConsumption• QualityofService

• Availability• TransmissionLatency• Capacity• ReconnectionTime

• CostFactors• CapitalExpenditure• OngoingDataTransmission• RelativeDeploymentCosts AntennaGainisoneofmanyfactorsthat

affectsCommunicationPerformance©TAVNetworks,Inc.2017 26

Overhead Communications• Radiocoverageimprovesby~5dBvs.groundcoverageattypical30-ftlineheight

RFSignalLevelatPotentialLSLocations MeasuredRFPathLossagreeswithstatisticalpredictions

ThisRFTestRigwasusedtoconfirmRF

CoverageatpotentialLineSensor

deploymentlocations


Underground Communications• Radiocoveragediminishes by5-35dBvs.groundcoveragedependingonlocalconditions

• Earthgrade• Compositeormetallicvaultcovers?

• Specialproblemsincludeflooding


Inductive Power Harvesting

• ApplicableforCurrentLineSensors• PrimaryCurrentRequirements?

• 6-12ampsfor“normal”functionality• Typicallyemploysupercapacitors• NOTbatteries

• 3-6ampsminimumloadtooperatein“lowpowermode”• Differentlevelsoffunctionalityinlowpower?• Maynotcapturewaveformsinthismode• Maynotbeabletoqueryhistoricaldata


Power Harvesting Limitations

Debrisinthemagneticjawpreventedthislinesensorfromproperlyharvestingpowerandrechargingits

battery

10Amps

0.2Watts


Establishing Deployment Guidelines• “RulesofThumb”fordeployment

• OptimalspacingofOverheadmeshradiorelays• AnticipatedreliabilityofOverheadCellularDatacomms• FeasibilityofUndergroundCellularDatacomms

• “FirstPass”networkdesignobjectives• 95.0%or99.5%coverage,andatwhatcost?• CoveragegoalsforPilotDeploymentprojectsmaydiffer

• PowerHarvestingLimitations• Averagecurrentatdesiredlocation

• Pre-installationNetworkDesign/FieldSurveyprocess


Product ComparisonTollgrade Sentient Eaton Grid-Sentry

Product LightHouseMV MM3 GridAdvisorII GS-200

FaultIndication Yes Yes Yes YesCurrentMeasurement Average Average/Max/Min Nominal/Fault Average/Max/MinRMSCurrentRange 3or6- 600A 6or12- 800A 3- 600A 10- 1000AMaxVoltage 69KV 90KV 69KV 138KVHarmonicsMeasurement Np Yes No NoWaveformCapture Yes Yes No YesRadioCommunications Cellular,WiFi Cellular,Mesh,WiFi Cellular Cellular,Mesh,WiFiSCADAInterface SMSorDNP3 DNP3 DNP3 DNP3OperationalTempRange -40to+60C -40to+85C -40to+85C -40to+65CWeight 6lbs. 6.5lbs. 2.5lbs. 3.5lbs.


Bracketing Fault LocationStanThompson

33

PG&E Company Profile

• PacificGasandElectricCompanyincorporatedinCaliforniain1905basedinSanFrancisco.

• PrimaryBusiness:Thetransmissionanddeliveryofenergy.PGEemploysapproximately20,000people.

• Goal:EstablishthebestoperatingUtilitiesintheU.S.Achievethefirstquartile


PG&E Company Profile (continued)• ServiceareastretchesfromEurekainthenorthtoBakersfieldinthesouth,andfromthePacificOceaninthewesttotheSierraNevadaintheeast

• 141,215circuitmilesofelectricdistributionlinesand18,616circuitmilesofinterconnectedtransmissionlines

• 42,141milesofnaturalgasdistributionpipelinesand6,438milesoftransportationpipelines

• 5.4millionelectriccustomeraccounts• 4.3millionnaturalgasaccounts


PG&E Business Benefits from Line Sensors

1. Reducecostofoutageresponse

2. Increasedsystemreliability

3. Assessmentoflinesensorcapabilities


Linesensorsareamodern,cost-effectivealternativetoanalogdevicesfordetectingandlocatingelectricdistributionlinefaults,whilealsoprovidingsignificantadditionaloperationalbenefits.

36

PG&E Line Sensor Use Cases • Fasteroutagerestoration

• “Narrowdown”thelocationofafault• Reduceoutageresponsetime

• Providemoreaccuratecurrentflowinformationtooperatorsandengineers

• Providemoreaccuratecurrentflowtoengineerstosupportbetterplanningofthedistributionsystem


Missing PiecesNoexistingsystemsthatcanutilizethebestofallexistingsystemsand

stillprovideinexpensiveinstantaneouscommunication


Currently In-Use Isolated Systems

GIS– GeographicInformationSystem

• EvolvedoveralongtimeperiodatPG&E


Current Isolated Systems (continued)

FLISR– FaultLocation,IsolationandServiceRestoration(FLISR)• Distributionautomationapplicationthatnetworksgroupsofswitchesonafeedertovastlyimprovethereliabilityofutilitydeliveredpowerby“localizing”outages.

OMS– OutageManagementSystem• Onlytracksliveissues,onceresolved,theyaregone.Rowbaseddatabase.


Current Isolated Systems (continued)

ILIS– OutageTrackingTool• Slowtoupdateandcumbersometofollow.Historicaloutlineofeventsaftertheyhavehappenedandhavebeenresolved.


Current Isolated Systems (continued)DMS– DataManagementSystem

• Operatorscanseeiconswhencallscomeinandthepowergrid,buttheydon’tknowwheretheoutageisandoftendispatchT-Mento20-40milesofpowerlinestocheckitout.


Line Sensors Are New & Must Integrate With Existing Processes


PG&E DTOC• TheDTOChousedtheLineSensorPilotOperationsTeam


PG&E Decided to Create a Distribution Technology Ops Center (DTOC)

• NewDepartment• DefinedRolesforparticipatingengineers


Line faults were actively monitored and reported during the pilot project


PG&E Line Sensor Pilot Project Timeline• 2014

• DTOCevaluatedaboutadozenLineSensorproductsfromvariousmanufacturers

• 2015• DTOCchose2overheadand1undergroundvendorforthepilotdeployment• Midyear,DTOCsuccessfullydeployedover1,300overheadlinesensorsonover200feederswithbothcellularandMeshtechnologies.

• 2016• DTOCdeployedover30undergroundcellularlocationsin2016,andover30rurallocationstoinvestigatesecondaryusecases


What were the Real Issues during the Pilot?

• Logisticalissuesofdeployingandinstallinglinesensors• ITIntegration– Eachdatabasehasit’sownsetofrequirements• CaptureDatafromthelinesensors– Whowillreceive&monitorthedata?Interpretdatafromfield- Reporttherightdatatotherightparty


Pilot uncovered who really cared about Line Sensors

1. ProgramSponsor2. Dispatcher3. FieldCrews4. EOCTeams


Line Sensor Project Metrics - Outage Benefit Analysis MethodologyCreatetheOutageReportCard:

• ILISReportandOISOutageReport(RawData)forsustainedoutages.

Filterouteventswithnopossiblebenefits:• Planned/crewrequestedoutages• Transmissionline/substation/sourcesideoutages• Eventswithabnormalswitching/FLISR• Non-mainlineoutages(fuses/transformers)• NolinesensorsbeyondarecloserorSCADAswitch

Answerfivequestionsregardingthoseoutageswithpotentialbenefits:• Didthelinesensorsbehaveproperly?• Wasthereaswitchingoperationavailable?• Weredispatchdirectivesavailable?• WasCFL(CalculatedFaultLocation)dataavailable?• WouldtheCFLdatahaveprovidedadditionaldispatchdirectives?


The kickoff for line sensor hardware installationIdentifythesitelocations

• Cellularcoverage?Mesh?• Meshischeapertooperate

Createtheplan/schedulefordeliveryandinstallation

CoordinatewithVendors,createpurchaseordertoreceiveinventory


Circuit Map Change Sheet• Oncethesitesare

qualifiedandselected,aCircuitMapChangeSheetwasapprovedbytheengineerinordertoinstalladeviceonthepowerline

• ThissheetgivestheT-linemantheauthoritytoinstallthedeviceandthelocationatwhichtobeinstalled.

• ThereisinformationneededfromtheT-linemantoberecordedthatneedstogobacktotheoperationsteam.


Inventory Master ListWhenaCMCSsheetisreceived,allofthedatafromtheT-linemanmustberecordedtobeabletoproducestatisticsandtogetthedevicesuploadedintotheirrespectivedatabases.


Enter device deployment data into Vendor Head Ends (Tollgrade)WhentheCMCScomesbackfromthefield,thedatareceivedneedstobeenteredintothevendorspecificheadendsothattheuntilwillbegintoworkandcollectdata.


Enter device deployment data into Vendor Head Ends (Sentient)

WhentheCMCScomesbackfromthefield,thedatareceivedneedstobeenteredintothevendorspecificheadendsothattheuntilwillbegintoworkandcollectdata.


Inventory Record was captured in GISWhenadeviceisinstalledonthegrid,thedeviceinformationneedstobeuploadedintotheGISdatabaseinventoryrecord.TheGISwillpushthedataintotheDMSservertocreatethelocationinfo.


An IT specialist on the project team was responsible for planning Data Flow


Remember this slide?


PI Historian served as the link to the Line Sensor devices and data


Loading Data as displayed via PI Data Link


Other examples of engineering data from Pi Historian

Communicationissues

Lowpowerissues

Faultycircuits

Outages©TAVNetworks,Inc.2017 61

PG&E selected 7 DNP3 points for common status reporting for all Line Sensors

• DataPointName

• LossOfCurrent

• HighCurrentStatus

• PermanentFault

• MomentaryFault

• LineDisturbance

• SagFault

• SurgeFault


• Tollgrade• FaultCurrent(a)• HighCurrent(a)• HighCurrentStatus(b)• LineDisturbance(b)• LineDisturbanceCurrent(a)• LossOfCurrent(b)• MomentaryFault(b)• MomentaryFaultCurrent(a)• PermanentFault(b)• PowerFactor(a)• RMSCurrent(a)• SagDipsExceedingThresh(a)• SagFault(b)• SurgeDipsExceedingThresh(a)• SurgeFault(b)

• Sentient– CurrentDirection(b)– FaultAlert(b)– FaultThresholdCurrent(a)– LossofCommunication(b)– LossofServiceAlert(b)– LossofVoltageAlert(b)– RMSCurrent(a)

Note:faultclassificationlogicintheDMS

DNP Points were mapped into PI Historian (vendor specific)


CMCS

GIS DMS

HeadEnd

CommunicationServer

Concentrator

InventorySensorMasterList

HeadEndEntry

EIEnterpriseIntegration

PIConnectorPIServerPIInterface

ProvisioningTaskListLineSensors

DNPIndex IT

HeadEndHeadEndHeadEndHeadEnds

Provisioning Task List was Complex!


415DCLocations:

DiagnosticsCenter

7PendingGISUploadEATONCOOPER:1TOLLGRADE:5

SENTIENTCELL:1

36NewLocations:

HeadendIntegrationinprocess;GISawaiting

receipt.

332PILocations:STAMI:106TOLLG:228

408GISLocations:EC:56

STAMI:107STCELL:12TOLLG:233

83NOT inPI

EATONCOOPER:57SENTIENTCELL:13SENTIENTAMI:1TOLLGRADE:12

168DMSLocations:

ALLTOLLGRADE

164NOT inDMS

SENTIENTAMI:106TOLLGRADE:58

Task List Status Tracking was also Complex


Final Product: Distribution Operators viewed Line Sensor status via DMS


• Onelinesensorsymbolperlocation(3sensors)displayedintheDMS• Select“LineSensorDisplay”optionintherightclickmenuoffaLineSensorsymboltoaccessreporteddata

• “NOCOM”tagnexttosymbolwhenLScommunicationslost

Normal• Orange=NoFault(default)

Faulted• BlinkingCyan=PermanentFault

Symbols in the DMS


RightclickonaLSsymbolandlaunchtheLineSensorDisplayto

seeitsdata

DMS example showing multiple Line Sensors


AnimatedSymbolsinDMSleadtofaultedzone

LSdata

SelectingaLSnamewilllocateitintheDMSmapandshowLoading

Databelow

Line Sensor Display after a Right-Click


Live DMS Display of LS Data1.SingleLine

Diagram

3.LoadingDataof

selectedLS

2.OperationalData

3devicesperlocation


Single Line Diagrams

• TheSingleLineDiagram(SLD)isusedasareferencetoindicatethelocationsofLSonthefeederinrelationshiptotheprotectivedevices

• LScorrelatewithrowsinthetablebelowthediagram• LSareshownasgraydiamonds(notanimated)intheSLD• Substationandprotectivedevicesareshownasredsymbols


Operational Data Table

• PerLSLocation:• Feeder– NameoffeederwhereLineSensorisinstalled• LineSensor– NameofLSlocation(OperationName)

• PerLSDevice:• PhaseID– LabelassociatedwithaLSdeviceatagivenlocationonthefeeder.Linesensorsareinstalledintriplets,e.g.,LS100254_1on“A”,LS100254_2on“B”,LS100254_3on“C”.

• LastLoadingData– LatestofperiodicallycollectedRMSCurrentvalues(e.g.,@15min)fromassociatedLS

• Status– CommunicationandPowerstatusofLS(detailsfollow)• Fault– detailsoffaultsreportedbytheLS(detailsfollow)


Status

Status

• Com– communicationsstatusofLSdevice• Blank=CommunicatingOK• “NOCOM”=LShasnotcommunicatedfor75minutesorlonger.Alldatacellswillshowasgraytext

• “NOTCOMMISIONED”=LSispresentintheDMSbutPIdatahasnotyetbeencommissioned.ThisisatemporarystatefornewlyinstalledLSwhilecommissioningisinprogress.Alldatacellswillbeblank

• Power• ON=AssociatedLSisenergized• OFF=notenergized


Fault Data

Fault

• PermanentFault• Fault=ColorcodeindicatingthepresenceofasustainedfaultreportedbyLSdevice(Orange=NoFault;BlinkingCyan=Fault;Gray=Statusunknown(whendevicenotcommunication))

• FaultCurrent=ValueandTimestampoflatestreportedpermanentfault

• MomentaryFault• FaultCurrent=ValueandTimestampoflatestreportedpermanentfault

Notice: Fault Current values older than 24 hours show as gray text; recent values as black


Loading Data

• RMSCurrenthistoricdatatrendofselectedLS(indicatedbyredrectangularframe)isshownbelowthetable

• Mouse-overthegraphforRMSvaluesataspecifictime• Selectgraphsectiontozoomin


Summary of Data Products from Project• 10minReportCards

• Operators• Engineers• T-Men

• MorningHealthChecktomakesuredevicesareonline• ReportingToolsformanagement

• Appshowingvariousmetric–periodicperformancereportschedulebased

• Determining“UpTime”

• SpecialAnalysis• Warriorsgame


Line Sensors on Warriors Stadium Feeders

• 6locationsestablishedonOaklandJ1110and1103feeders

• Loadvalueslooknormalandconsistent.• NoeventsfromLineSensordata.• Investigatingoutofphaseononesensor.


EGTDiagnosticCenterOaklandArena- LineSensorMonitoring

OaklandJ1110

AthleticsVS.TigersMay29th

Peak161Amps

AthleticsVS.TwinsMay31th225PeakAmps

• 7locationsonactivepowerfeedstotheStadiummonitoringtheWarriorsgame• Loadvalueslooknormalandconsistent(peakingatgametimes)• NosuspecteventsfromLineSensordata

Game7WarriorsVS.Thunder18:00

AthleticsVS.Twins13:05May30th218PeakAmps

AthleticsVS.TigersMay27th

Peak221Amps


AthleticsVS.Tigers

May28thPeak215Amps


May26thPeak196Amps


Tollgrade


Sample of Wave Form from Head End


Value added use cases for Engineers:• Failingequipment

• Capbanks,transformers,orunreliablemetering

• Balancetheloadbetweenthephases• Realtimecurrentreadings

LowcostsubstitutetoSCADA• DistributedGeneration


Characteristic Waveforms

FuseOperation

CapBankoperationCablejointfault/Splice

LoadSwitching


CFL


DG reports


Calculating Fault LocationStanThompson

88

First Let’s Define CFL: The Broad Definition

TraditionalCFL(TCFL):• Calculationoffaultlocationbasedsolelyondata

collectedatsubstationusingVoltage/Currentreadings.• AnexampleofhowtodothisusesCYME

ComprehensiveCFL(CCFL):• Calculationoffaultlocationisbasedon:

• Voltageandcurrentmeasurementsmadeatthesubstation

• Currentmeasurementmadeontheprimaryofthedistributionline(LineSensors)

• Voltagemeasurementsmadeontransformersecondariesalongthedistributionline.(VoltageSagMonitors)

CalculatedFaultLocationisanattempttodeterminethelocationofafaultwithinseveralpolespans


Traditional Calculated Fault Location (TCFL)OurExperiencetoDate

TCFLcalculatesthenumberofwire-milestothefaultlocationusingCYMEcalculationvoltageandcurrentdatacollectedatthesubstation

ActualFault

Location

IndicatedFaultLocations

TypicalResultUsingSubstationCFL

Strengths:• Usesdataalreadyavailable

fromlinereclosersandsubstationrelaysandalternativetolargelinesensorrollout

• Reasonablejobofcalculatingthedistance

Shortcomings:• Identifiesmultiplepotential

locations– numerouslocationsdonotleadtomeaningfulbenefit

• Errorsareoftenintroducedduetoimprecisemodelingassumptions©TAVNetworks,Inc.2017

Original Visualization of CYME Analysis


New Visualization of CYME Analysis


Results: Bracketing of a Fault Location Using Line Sensors

PossibleFaultLocation

ActualFault

Substation 1234

LS100128@ SW 4223

30.5

R4676

SCADA LS100146

@ SW 4115

40S9267SS 9273

R4068

SCADA

R4782

SCADA

SensorLocation Date/Time SensorName Phase RMSCurrent40 5/18/201617:12 LS100146_1 A 150440 5/18/201617:13 LS100146_3 B 27640 5/18/201617:12 LS100146_2 C 1447

InthisexampletheLineSensorsbracketthe

faulttothetopbranch.

LineSensorsbracketafaultlocation.LineSensorsprovideloadingdataforswitchingandcapacityplanningdecisions.Strengths:• Easytoinstall&tounderstandfaultlocation

information• Reasonablejobofcalculatingthedistance• PotentiallyprovidesadditionaldataforCCFLmodel• Providesdataforswitchingandcapacityplanning

Shortcomings:• Willnotworkwithlowcurrent• 10xthecostofnon-communicatingfaulted

circuitindictors(FCI)


Bracketing of a Fault Location Using Line Sensors

PossibleFaultLocation

ActualFault

Hollister 2104

LS100128@ SW 4223

30.5

R4676

SCADA LS100146

@ SW 4115

40S9267SS 9273

R4068

SCADA

R4782

SCADA

SensorLocation Date/Time SensorName Phase RMSCurrent40 5/18/201617:12 LS100146_1 A 150440 5/18/201617:13 LS100146_3 B 27640 5/18/201617:12 LS100146_2 C 1447

InthisexampletheLineSensorsbracketthe

faulttothetopbranch.

LineSensorsbracketafaultlocation.LineSensorsprovideloadingdataforswitchingandcapacityplanningdecisions.

Strengths:• Easytoinstall&tounderstandfaultlocation

information• Reasonablejobofcalculatingthedistance• PotentiallyprovidesadditionaldataforCCFLmodel• Providesdataforswitchingandcapacityplanning

Shortcomings:• Willnotworkwithlowcurrent• 10xthecostofnon-communicatingfaultedcircuit

indictors(FCI)


ShortcomingsNecessitateMovingfromTCFLtoCCFL

FillingtheGapwithVSMs:1. ReducethenumberofpotentiallocationsfromTCFL2. ImprovetheaccuracyofthemodeledlineimpedancesinTCFL3. ProvidesensordatainlocationswhereLSisnotpractical

TCFLShortcomings

• Estimatesafaultdistancefromsubstationbutdoesn'tdeterminewhichbranchthefaultison(andtherecanbemany)• Modelingassumptionsarenotpreciseandcanleadtoerrorsinprediction• Lackofcurrentmeasuringdevices?

LSShortcomings

• LineSensorsdeterminewhetherthefault/currentpassedtheirparticularlocationhoweverthismaynotlocalizetheactualfaultlocation.• Theydon’tworkfardownthelineduetolackofcurrent,

• Cannotinstallifwireistoosmall,moreexpensiveinstallation• LineSensorspreciselymeasurethecurrent;butcannotmeasurethevoltage

The “Calculation Gap” that led to use of Voltage Sag Monitors


Voltage Sag Monitors Monitors Help Fill The Gap

• VSMspreciselymeasurethevoltagethatlinesensorscannot• Thefindingsthusfarindicatethatvoltagesagmonitorshaveaplace&thereismuchmorepotentialforleveragingdata


Our Experience to Date with VSM• VoltageSagMonitorsthatmeasureandreportvoltagedropduringfaultevents

• AdditionalVSMsensorcomplementsaforementioned• Supplementsthecalculationforfaultlocation.

ThemeasuredRMSvoltageduringthefaultevent,whencombinedwiththeVSM

installationlocationalongthedistributionline,canbeusedto

predictthefaultlocation

VoltageSag


Using Comprehensive Data to Pinpoint CCFL

Hollister 2104

LS100128@ SW 4223

30.5

R4676

SCADA LS100146

@ SW 4115

40S9267SS 9273

R4068

SCADA

R4470

SCADA

V

4ad69323.8%

V

4ad69299.7%

V

4ad69b10.9%

V

4acbb449.3%

V

4ad64791.9%

R4782

SCADA

R41808SCADA

V

4ad64620.6%

FaultLocationUsing:1. SubstationCFLAlone2.TCFLplusLineSensors3.TCFL,LS,plusVoltageSag


VSM Conclusions: More “Bang for the Buck”• VSMscanbedeployedallthewaytotheendofthefeeder

• VSMsmakeCFLaccurate

• VSMsprovidepowerqualityandvoltagedataimportantforDG

• AugmentationofTraditionalCFLwithVSMconvertsa“nice-to-know”applicationtoamission-criticalbenefitforoperators

• PGEfoundvalueusingthevoltagesagmonitors


VSM Relationship to Smart Meters• Weinstalled5Msmartmeters.

• CantheyfulfillthefunctionofaVSM?Yes...Inprinciple,butthereisno“quickfix.”Time,moneyandresearchwillbenecessary.

• SMaremissioncritical– billing– wouldrequirehardwareimplications&thiswouldbeamanyyearprocess.

VSMsareimmediatelyapplicable©TAVNetworks,Inc.2017

BothTraditionalCFL&LineSensorshadshortcomingsthatcanbemitigatedwithuseofVSMs

Recommendations

• VSMsareacostattractivesolutiontosolvingtheCCFLpuzzle;(ofoursolutionsthisisalowercostapproach.

• VSMfunctionmaybeincludedinaSmartMeterfunctioninthefuturebutthatisalongwayoff.

• VSMsprovideasolutionforneartermCCFLefforts.

• VSMrolloutwillpayforitselfquickly&willfilltheneedduringtheyearsitwill taketodevelopSmartMeterimplementation


102

• WhatworkedforPG&Eisacombinationoflinesensors,CFL,voltagemonitorsandexistinginfrastructure,resultinginthedisseminationofcrucialinformationwithin10minutes

Conclusions


BREAK(15 minutes)


Asset ManagementJeffTeuscher

104

DP&L OverviewServingtheRegionforOver100Years

• 6,000squaremilesin24countiesinOhio

• 1,400employees• Generation• CustomerServiceOperations• FieldOperations

• DP&LisanAEScompany• IndianapolisPower&LightissisterAEScompany


AES, A Fortune 200 Global Energy Company

• 17countriesacross4continents• 35gigawatts(GW)ofgeneratingcapacity

• 7 utilitycompaniesincluding8GWofgeneratingcapacity

• $15billioninannualrevenues• Aglobalworkforceofapproximately21,000people


Asset Management Function• Allowassetstobemonitoredreal-time• Trackequipmentoperationstodecidemaintenancecycles• Powerqualitydatacanbecapturedandanalyzedtopredictfutureequipmentfailurethroughdatatrending

• SensordatacanfeedDistributionManagementSystemsforreal-timemodelingofthedistributionsystem.Allowsforoptimizationoftheutilityassets

• Sensorscanprovidemanydatapointsforassetsystemstoanalyze• Dataiskeytobetteranalyticsandthisleadstobetterassetmanagement


Line Sensors - an alternative to expensive distribution assets

• HydraulicRecloserandSensorvsElectronicRecloser• CircuitMonitoringatSubstationvsRTUandDigitalRelays• PlanningTools– SensorsMonitoringLoadvsLoadLoggerTechnology

• MonitorCapacitorGroundforcurrentflow.Signalsablownfuseonthethreephasebank.

• Monitorcircuitbalanceatpointsalongthecircuit.• Potentialtouseforvegetationgrowth.Basedonsmallinterruptionorsmallcurrentfluctuations.

• Faultdetectionandreportingonthedistributionsystem


Sensor as Circuit Monitor at Substations• SubstationsthatdonothaveanRTUinstalledtoday.• Sensorswillbedeployedoneachcircuitleavingthesubstation.• Circuitmonitoringcanbeachievedatmuchreducedcost.SensorsareApproximately$3500percircuitinstalled.

• RTUwithcommunicationsisapproximately$50k- $75kbeforedigitalrelaysareinstalled.

• Sensorallowscircuitloading,alertwhencircuithasoperated,aggregateofcircuitloadsprovidestransformerloading.

• Sensorsaremonitoringonly,whereasRTUprovidescontrolatthesubstation.


Sensors as Planning Tools• Sensors=$1000each– LoadLoggersare$1600each.

• Sensorsprovidedatanearreal-timeloaddatatotheengineers.

• Sensorsdon’tneedbatteries.• LoadLoggersneedtobeinstalledforaperiodoftimeandthenremovedtoretrievethedata.

• Loadloggerneedssoftwaretodownloaddata.

• Sensorsuppliesdatatoutilitysystemofchoice.


Hydraulic Recloser and Sensor • CostSavingsof$2000perinstallation

• (HydraulicRecloser+Sensor=$2500+$1000=$3500• ElectronicRecloser=$5500)

• Sensorwillalerttheoperationscenterwhenithasoperatedandwenttolockout.

• Sensorwillallowfortrackingnumberofoperationsontherecloser.

• Sensorwillprovidereal-timeamperagedatatounderstandloadingontherecloser.


Program at DP&L• Installalinesensoratfourlocationswithhydraulicreclosers.• Unitisinstalledontheloadsideoftherecloser.• Installationisononeruralcircuit.


Circuit One-line Diagram


Data from the Sensor for Recloser Monitoring and Maintenance• Simulatecounterwithoperationsofsensor.• Loadingontherecloser•Open/closetimingoftheoperations•Totalinterruptenergyontheunit


Sensor Data Chart on 3 single phase reclosers


Power Quality MonitoringJeffTeuscher

116

Problem• LimestoneMiningOperationemployeeswerereceivingshockswhentheyweresettingchargesintothewall.

• Customercontactedtheutilityforhelponfindingtheproblemasthecustomerwasconcernedforemployeesafety.

• Two13.2GroundedYprimarymeteredservicestothemine.• Bothservicesareclosetotheutilitysubstation• CustomerrunsfourwireoverheadprimarytomultipleMV-LVtransformers.• GroundingpracticeswereMSHAnon-coal(primaryneutralbondedtosecondaryneutralandlocalearthelectrode)

• Customerthoughttheydidnotusetheneutralbutwasunsureoftheactualuseoftheneutralfortransformersandother

• CustomerwasunwillingtotakeanyoutagestoseparatephasesandneutralfromutilityforstandardNEV(neutraltoearthvoltage)test.

• Detailedinspectionofcustomerfacilitieswasoverlydifficultandexpensive


Problem Area in Mine


Circuit Map to Limestone Mine


Diagnostics/Findings• Criticaltoknowdetailsofneutralcurrentinneutralwirewithoutrequiringanoutageforthecustomeroranextensiveinspection

• TotalcurrentandcorrelationtoNEV• Amountofcurrentduetocustomerload• Amountofcurrentduetosubstationneutralreturncurrent

• PQmeteratmeteringpoint• Measuredneutralcurrentdemandedbycustomer• Measuredfrequencyspectrumofdemandedneutralcurrent• MeasuredNEV.

• Linesensor• Measuredthetotalneutralcurrent(customerdemandandsubstationreturn)• Measuredfrequencyspectrumoftotalcurrent– especiallyimportantthirdharmonic.• TrenddatawenttoPIdatahistorianforcorrelationwithPQandrevenuemeter

• NeutralcurrentandNEVatthesubstationwasdeterminedtobealmostall3rd harmonic.• Thisofferedanopportunitytofurtheridentifycurrentcontributions• Thirdharmonicwouldbesubstation• Fundamentalwouldmostlybecustomer


Line Sensor Current Chart

TSAA085228.217

TSAA0851Bad

10/20/2016 1:40:35 AM10/11/2016 4:20:35 AM 8.89 days

Plot-0

0

5

10

15

20

25

30

0

30 Ledtofindingcapacitorwithblownfuse

Highneutralcurrentclearedaftertreeoutage


Conclusion• NeutralcurrentmonitorsconfirmedNEVwascausedlocallyandnotbyutility

• Neutralcurrentsinrevenuemeterandlinesensorpredominantlyfundamental.• Neutralcurrentmagnitudeinrevenuemeterscloselymatchedthelinesensorcurrentmeasurement.

• NEVcorrelatedwithcurrentrecordedinPIbylinesensor.• Nooutageorextensiveinspectionwasneeded• Neutralcurrentmonitorsconfirmedfaultyequipmentononeserviceandblowncapacitorfuseontheother

• Faultyequipmenthadhighlyfluctuatingneutralcurrentandequipmentfailedwhilethelinesensorwasinservice.Linesensorconfirmedthecurrentreductionafterrepairs.

• LinesensorandPQmeteronotherserviceindicatedneutralcurrentmaybeduetocapacitor.Capacitorwaseasilylocatedanddidhaveblownfusewithotherphasesconnectedtoneutral.

• Strayvoltagewasfromthecustomerhighneutralcurrents• LightingcarriedNEVintotheminethroughtheequipmentgroundingconductorthatwasbondedtotheprimaryneutralasperMSHAandNECrequirements

• Highmoisturecontentandstrataconductivity“energized”largeareasoftheminewall.• Customernowunderstandsimportanceofverylowprimaryneutralcurrentandhasestablishedamonitoringprogram.


Other PQ Sensor Charts

-2500

-2000

-1500

-1000

-500

0

500

1000

1500

2000

1 31 61 91 121

151

181

211

241

271

301

331

361

391

421

451

481

511

541

571

601

631

661

691

721

751

781

811

841

871

901

931

961

991

1021

1051

1081

1111

1141

1171

1201

1231

1261

1291

1321

1351

1381

SensorAmps

ValuesAmps

Potentialofanintermittentfault–Couldrepresentafailinglinearrestor


Sensor PQ – Harmonic Distortion

-200

-150

-100

-50

0

50

100

150

1 30 59 88 117

146

175

204

233

262

291

320

349

378

407

436

465

494

523

552

581

610

639

668

697

726

755

784

813

842

871

900

929

958

987

1016

1045

1074

1103

1132

1161

1190

1219

1248

1277

1306

1335

1364

1393

ValuesAmps

ValuesAmps

LinefaultandHarmonicdistortionofthecurrentwaveshape.


Sensor Data


Vegetation ManagementJoeTavormina

126

Grid Maintenance Today

• Mostlyreactive(followingoutage)• Agingassets• Decliningnumberofpersonnel• Outagesaredifficulttolocate• Rootcauseofoutageoftennotresolved

Credit:MarionTremblay,Hydro-QuebecIREQ,DistributechFebruary2016


Outages may be avoided by locating and characterizing non-persistent faults

Credit:MarionTremblay,Hydro-QuebecIREQ,DistributechFebruary2016

• Non-oxidizedconductorindicatesarecentfaultprobablycausedbyvegetation


Vegetation issues lead to financial liabilities

PG&Etopayoutatleast$350millioninButteFireclaimsByDanaM.Nicholsdana@calaverasenterprise.comNov28,2016

Almost100ofthe1,856individualswhoaresuingPacificGasandElectricCo.overlossescausedbytheButteFirehaveagreedtosettlementswiththeutilitycompanyanditscontractorTreesInc.,accordingtoacourtdocument.

AttorneysfortheplaintiffsandthedefendantssaidinajointcasemanagementstatementfiledNov.18that53householdsincluding98plaintiffsandatotalof123individuals(someofwhomwerenotnamedplaintiffs)havesettledtheirclaims.

TheButteFirethatbeganSept.9,2015,burnedmorethan70,000acresanddestroyedmorethan500CalaverasCountyhomesaswellashundredsofbarns,shedsandwellhouses.TheCaliforniaDepartmentofForestryandFireProtectionconcludedinareportissuedinAprilthatatreetrimmingcrewhiredbyPG&Efailedtoremoveagraypinethatlaterfell,contactedapowerline,andstartedthefire.

PG&E,ContractorsToPay$51MToEndCalif.WildfireSuitsBy KurtOrzeck

Law360,LosAngeles(June6,2013,8:31PMEDT)--PacificGasandElectricCo.anditscontractorshaveagreedtopay$50.5milliontosettlelitigationovertwoCaliforniawildfiresthatburnedmorethan18,000acresofnationalforestandcost$13.5milliontosuppress,theU.S.DepartmentofJusticeannouncedThursday.

TheU.S.allegesthatthedefendants'neglectcausedthePowerFireandtheWhiskeyFire,whichoccurredinOctober2004andJune2008,respectively.ThefirstfireoccurredinEldoradoNationalForestinAmadorCountyinaremotelocationneartheSaltSprings...


Assessment of non-persistent faults from Hydro-Quebec• Non-persistentfaultsrepresentupto70%offaultsindistributioncircuits

• Typicallycausedbyvegetationcontactordefectiveequipment

• Oftendeteriorateintooutages• Oftenresponsibleformanyrepetitiveunsolvedoutages

Credit:BryanTexasUtilitiesWebSite


Voltage Sag Measurements can be used to Locate Fault and Identify Cause

Reference:MarionTremblay,Hydro-QuebecIREQ,DistributechFebruary2016

• Hydro-QuebecMILESproject• Locatedandrepairedlooseconductorthatheatedandexpandedunderhighcurrentload

• Locatednon-persistent,repetitivefaultduetovegetationinpresenceofwindgusts(norain)

• PG&ELineSensorPilotproject• AddressingliabilitiesrelatedtoforestfiresinthefoothillsofEasternCalifornia


Analysis of non-persistent faults requires analytics beyond current practice

• Assetassociationsandlocation• Eventrecords• Backgroundanalysis• Notificationsmanager• e.g.SensorConnectbyTAVNetworks,Inc.

Sensor SensorManager

SensorDB

DataEvent

DATA

ACK

SaveEventData

OK Sensor

Sensor

Sensor

SensorManager

WebService

WebClient

ManagementInterface

SensorInterface

SensorData

SensorDBInterface

ConfigData

ConfigDBInterface

WebClientInterface


Potential Benefits• Reductionofoutagefrequency(upto~50%)

• ReductioninSAIDIIndex(upto~60%)

• ReductioninOutageswithUnknownCause(upto~90%)

• Avoidanceofunnecessaryinvestment(Millionsof$$$)

• Mitigationofliabilityforwildfires

Credit:AsplundhWebSite


Lessons Learned from Line Sensor Deployment ProjectsJaredHafer

134

Planning a Line Sensor Project – Scope• WhatBusinessBenefitsaredesiredfromtheLineSensorDeployment?

• Needs• Wants• Expectations

• Anticipationofscope“creep”?• Plantopreventthis“creep”?


Articulating Anticipated Business Benefits• FaultDetection,Location,andRapidRestoration

• DecreaseWindshieldTimeforTroublemenbyknowingaprecisefaultlocation• Decreasedoutagedurationsforcustomersduetofasterresponses

• PowerQualityMonitoring• Distributionplanning• Troubleshooting

• AssetManagement• CostsavingsinOperationsandMaintenance• Substationautomation

• OtherbenefitstoutilitiesfromLineSensors?


Planning a Line Sensor Project – DeploymentIdentifydeploymentlocations

• Outsidesubstation• Afterfirstrecloser• Knowntroubledareas• NoSCADAareas• ForReliabilityorPlanning?

Qualifylocations• Currentonfeeder• Radionetworkcoverage• Localconditions(i.e.insidevault?)

• FieldInspectionConfirmation


Installationorders/maps• Lat/long• ProtectivedeviceID• Conductorsize(2/4/6AL/CUmayneedalineguard)

• Hotstickvsrubbergloveinstall• Access/propertyissues

Installationtraining/documentation

• ProcessfordeterminingRFcoverage,linecurrent,phaseID,andlocation

• DeploymentdatamanagementLine Guard

137

Deployment Schedule Issues/Risks• Significantschedulerisksduringdeployment

• Weather- Onewouldbeshockedtolearnhowmanyofourclientsforgettoconsiderwintersnoworextremesummerheatwhenputtingtogethertheirdeploymentschedules.

• UninformedCustomers- Uninformedcustomerswillasktheirneighborsortheinternetwhatthenewdevicebeinghungontheirpowerlineis.Besuretoletcustomersknowwhatyouaredoingandwhy,sotheyareproperlyinformed.

• LegalIssues- Canadevicebeinstalledwhereitisdesired?Ispermissionneededorarerightofwayagreementsrequiredinadvanceofinstallations?

• UnreliableVendors- Whathappenswhenanequipmentvendormissesadeliverydate,orequipmentfailsinthefield?

• Howcanknownprojectrisksbemitigated?


Planning a Line Sensor Project – QA• Whatisthedeploymentsuccesscriteria?• Howwillsuccessmetricsbemonitored/tracked?• Whatprocesseswillbeputintoplacetoremediatedevicesthatarenotfunctioningproperly?

Deploymentlocationswerescreenedforcommunicationsviability.Theoneontherightwasdeemedtoorisky.©TAVNetworks,Inc.2017 139

Planning a Line Sensor Project - Resources

• Whatexistingresourcesareavailableforassignmenttoproject?

• Whatadditionalresourcesneedtobeengagedfortheproject?

• Howwillhumanresourcesbemanagedfortheproject?


Planning a Line Sensor Project – IT Integration• Legacyinformationsystems

• GIS• DataHistorian• OutageManagement• DistributionManagement• SCADA

• DatarepositoryforLineSensors• Deploymentdatamanagement

• Paper-based?• Electronic?

DMS

SCADA

Gateway Supplier-SpecificHeadEnd

DNP3

VPNTermination

LineSensor Line

Sensor

LineSensor

ODN

UDN

NoProvisioningPermittedByPolicyfromwithinODN

Operators&DataUsers

One-WayDataPath


Planning a Line Sensor Project – Ops Integration

• LegacyOperationalProcesses

• NewDecisionProcesses

• PrimaryUsers• ExistingGUIs• Constraints

• ExecutiveUsers• Metrics• PeriodicReporting


Lesson Learned – IT Development• LineSensordeploymentdrives:

• Accelerationoforganizationaldecisionsregarding“AdvancedDMS”• Exposenetworksecurityconcerns• HighlightthesignificantcostassociatedwithITassetsanddevelopment

• Response:• PostponementofITIntegrationduringpilotproject• Adoptionofhostednetworkmanagementanddatacollection


Lesson Learned – Deployment Planning• LineSensordeploymentsuccessrequiresconfirmationof:

• RFCoverage• LineCurrent• PhaseIdentification• Location• LocalConditions

• Response:• FieldEngineeringisrequired• Appropriatefieldengineeringresourcesarerequired• Appropriatefieldengineeringtoolsarerequired


Lesson Learned – Deployment Data• LineSensoradoptionrequires:

• Integrationwithlegacyinformationsystems• Retoolingoflegacyoperationaldecisionprocesses

• Response:• Paper-basedprocessesareslowandtime-consuming• Installationdatacollectedonpapergetslost• Deploymentprojectplanneedsspecialconsiderationofthisproblem• Datamanagementtoolsthataddressthisproblemareneeded


Lesson Learned – Field Engineering Tools• FieldEngineeringToolsconservesignificanttimeandcostduringadeploymentproject

• LocationQualification• DeploymentDataCollection&Management


Q&A(15 minutes)


Index of AbbreviationsNLOS – Non Line Of SightODN – Operational Data NetworkOMS – Outage Management SystemPG&E – Pacific Gas & Electric CompanyRTU – Remote Terminal Unit (part of SCADA system) SCADA – Supervisory Control and Data AcquisitionUDN – Unsecured Data Network


ADMS – Advanced DMSAMI – Automated Metering InfrastructureCPUC – California Public Utility CommissionDA – Distribution Automation DMS – Distribution Management SystemDNP3 – A Common Serial Communication ProtocolDP&L – Dayton Power & LightNERC-CIP – DoE Regulating Entity

148

Presenters – UU Course 202• Joe Tavormina

• Principal,TAVNetworks,Inc.• TAVNetworksisaCommunicationsandSensorCompany• Email:[email protected],Tel:(775)831-0200

• Jeff Teuscher• OperationsManager,DaytonPower&Light(DP&L)• Email:[email protected],Tel:(937)331-4090

• Stan Thompson• OperationsProjectManager(Contract),PacificGas&ElectricCompany• Email:[email protected],Tel:(775)415-1000

• Jared Hafer• DeploymentProjectManager,BaltimoreGas&Electric(Contract)• Email:[email protected],Tel:(707)415-1000


Course Evaluation

• Pleasecompetethecourseevaluation– availablefromyourcellphone!Textthe#80464withthe5digitcodeattheendoftheUUcoursetitle

• CourseCode:16564• Fillinyournametoenteradrawingtowina$100Amazongiftcard!


Thank you for AttendingUU202:LineSensorDeploymentforDistributionAutomation:Practical

Deployment,DataCollectionandUseCases(#16564)

TO DOWNLOAD A COPY OF THIS PRESENTATION VISIT WWW.TAVNETWORKS.COM/DISTRIBUTECH


line sensors for distribution automation · ©tav networks, inc. 2017 31. product comparison...

Documents