An Update on HydroAn Update on Hydro--QuQuéébec bec Advanced Distribution Automation Advanced Distribution Automation

ProgramProgram

Georges SimardGeorges SimardOrientations Orientations dudu rrééseauseauDirection Direction GestionGestion de de l'actifl'actif -- VPRDVPRD

22

OutlineOutline1. General approach

2. Hydro-Québec's ADA projects1. Volt and VAR Control

2. Fault location

3. Underground Vault

4. PQ Data from Distribution substation

5. Data management – software analysis

3. Next steps

4. Hydro-Québec's Distribution roadmap

5. Conclusion

July 2006July 2006

33

Intelligent Distribution NetworkIntelligent Distribution NetworkFlow of InformationFlow of Information

DATA(Using what?)

Voltage

Fault Currents

Load Currents

Temperature

Number of Operations

Applications(How?)

Voltage Control

Optimised Load Flow

Fault Location

Faulty Equipment

Power Quality Evaluation

Technologies

Business drivers (Why?)

Energy Efficiency

Reliability

Distributed Resources

Power Quality

Customer Satisfaction

• T• T • T

•T

•T

44

Intelligent Distribution Network Intelligent Distribution Network Flow of DecisionFlow of Decision

DATA(Using what?)

Voltage

Fault Currents

Load Currents

Temperature

Number of Operations

Applications(How?)

Voltage Control

Optimised Load Flow

Fault Location

Faulty Equipment

Power Quality Evaluation

Technologies

• T• T • T

•T

•T

Business drivers (Why?)

Energy Efficiency

Reliability

Distributed Resources

Power Quality

Customer Satisfaction

55

Distribution Network Distribution Network –– DA RoadmapDA Roadmap

Business DriversBusiness Drivers ProjectsProjects Years Years .•• ReliabilityReliability Remote ControlRemote Control 2006 2006 --20122012•• Energy EfficiencyEnergy Efficiency DER HQ ProgramsDER HQ Programs 2006 2006 --20152015•• Energy EfficiencyEnergy Efficiency Voltage ControlVoltage Control 2008 2008 --20152015•• ReliabilityReliability Fault LocationFault Location 2008 2008 --20152015•• ReliabilityReliability Underground VaultUnderground Vault 20082008-- 20152015•• Power Quality (PQ)Power Quality (PQ) PQ MonitoringPQ Monitoring 2008 2008 --20152015•• Energy EfficiencyEnergy Efficiency Load side ManagementLoad side Management 2009 2009 --20152015•• Customer SatisfactionCustomer Satisfaction Predictive MaintenancePredictive Maintenance 20092009-- 20152015•• ReliabilityReliability Automatic ReconfigurationAutomatic Reconfiguration 2010 2010 -- 20152015•• Customer SatisfactionCustomer Satisfaction Customer PortalCustomer Portal 2010 2010 --20152015•• Energy EfficiencyEnergy Efficiency MicroMicro--gridgrid 2015 2015 -->>

DistributionTransmission

Energy

Energy

ResidentialResidential

IndustrialIndustrial

InstitutionalInstitutional

Customers

66

VOLT and Var Control

77

Improve energy efficiency by reducing the voltage

The amount of energy bought at marginal price (8,3¢/kWh) and delivered to customers (6,5¢/kWh) Peak load of the systemEnergy losses

Project ObjectivesProject Objectives

88

Voltage level at a customer installation at the remote end of a feeder

105

110

115

120

125

Time over one year

Volta

ge (V

)

With Voltage Control

Present (without VC)

Benefit

Voltage control leads to energy saving.

Normal voltage range as per (C.235)

Voltage control Voltage control benefitbenefit

Summer

99

Volt Volt andand VARS Control Project ConceptsVARS Control Project Concepts

Minimum CSA C235 = 115 V

Substation End of feeders

123 V

Actual

Volt andVARS Control

VoltControl

1212

1010

Volt and VARS Control Intelligent SystemVolt and VARS Control Intelligent System

Regulation control

Voltage setting

Sensor

115 V

Control Logic on

Regulation andOnline capacitors

SensorSensor

Sensor

Telecommunications

Sensor

Current system The control logic must select the voltage level to use from all the voltage readings from the remote end sensors and capacitors

123 V

p.5

1111

Phase 1: Volt Reduction Phase 1: Volt Reduction Reducing voltage settings at the substation to reduce energy and peak load

Studies to be done to fix the voltage level (must consider type of load – constant impedance, power or current proportions)Must keep a margin for dynamic operations and unbalanced loadsPower Quality monitoring may be needed to insure respect of C235

Phase 2: Volt and VARS Control Phase 2: Volt and VARS Control Voltage and VARS controlled through remote sensors on the feeder

Intelligent system to optimise online capacitors management and volt control in a single system

Project DescriptionProject Description

1212

ResultsResults and and nextnext stepssteps

Phase 1 : Manual voltage reduction test at a typical distribution substation confirmed an average CVR of 0,4 over one year (1% of voltage reduction = 0,4 % of energy conservation)Phase 2 : Demonstration project – End 2008HQD aims to deploy a global Volt and VARS Control project by 2008-2015

1414

Fault location

1515

HydroHydro--QuQuéébec's Distributed Approachbec's Distributed Approach

Voltage Drop Fault Location (VDFL) Distributed PQ analyzersVoltage Sags waveformsMost feeders require only 4 measurement sitesEasy measurement

Low voltage (customer side)GPS not required (no precise synchronisation required)Calibration not needed

-25000

-20000

-15000

-10000

-5000

0

5000

10000

15000

20000

25000

0.05 0.07 0.09 0.11 0.13 0.15 0.17 0.19 0.21 0.23 0.25

VA VB VC

-25000

-20000

-15000

-10000

-5000

0

5000

10000

15000

20000

25000

0.036 0.056 0.076 0.096 0.116 0.136 0.156 0.176 0.196 0.216 0.236

VA VB VC

-25000

-20000

-15000

-10000

-5000

0

5000

10000

15000

20000

25000

0.05 0.07 0.09 0.11 0.13 0.15 0.17 0.19 0.21 0.23 0.25

VA VB VC

Substation

D

E

F

Patent PendingPatent Pending

1616

VDFL Basics (1)VDFL Basics (1)

V

D

D F

E

Distance to faulty lateral

1717

Vli

VlrVd

VD

VF

VE

VDFL Basics (2)VDFL Basics (2)

d1

D FE

z1

z2

d2

z3

d3

VDFL deduce :Fault currentPosition of faulty lateralDistance to faultArcing voltage

1818

MILE MILE -- Voltage drop on phase CVoltage drop on phase C

1919

MILE MILE –– Fault Probable LocationsFault Probable Locations

2020

Burning traces located on conductor at mid distance between poles.

Fault locatedFault located

2121

1

4

7

5

3

2

3

0 0 0 0 0

1

0

1

2

3

4

5

6

7

8

0-50

50-10

010

0-150

150-2

0020

0-250

250-3

0030

0-350

350-4

0040

0-450

450-5

0050

0-550

550-6

0060

0-650

Absolute error (m)

Occ

uren

ce

Average absolute error: 188 mError spread: -315m to 619 m

Fault Location AccuracyFault Location Accuracy

95% of the distribution faults located are within 332m

2222

AdvantagesAdvantages

The main advantages are:PRECISION: faults are located within an average absolute error of 188 meters (617 ft). Independent of fault contact impedance.INTEGRATION: with existing distributed advanced systems such as AMI or ADA: The same sensors used for VDFL can be used for PQ qualification of the system and possibly voltage andVAR control. This system needs only software and computers to treat the data that will lead to fault location.TIME STAMP NOT NEEDED: waveshape synchronization is done through the software.ABSOLUTE PRECISION NOT NEEDED: The VDFL technique automatically compensates for lack of monitoring accuracy.

23© 2007 Electric Power Research Institute, Inc. All rights reserved.

Approaches for fault location

• Fault location based on voltage monitoring at distribution system locations (Hydro Quebec)

• Fault location based on voltage and current monitoring at substation (EPRI PQView)

• Fault location with fault current indicators (communicating)

24© 2007 Electric Power Research Institute, Inc. All rights reserved.

Example of waveforms used for fault location

-20

0

20

-5

0

5

0.00 0.05 0.10 0.15

Single-Phase Fault Evolves into Two-Phase

EPRI/Electrotek PQView®

Vol

tage

(kV

)C

urre

nt (k

A)

Time (s)

Va Vb Vc Ia Ib Ic

1B 2AB2.195 2.216

10.012.515.017.5

1

2

3

2.5

5.0

7.5

10.0

0.05 0.10 0.15

Single-Phase Fault Evolves into Two-Phase

Vol

tage

(kV

)C

urre

nt (k

A)

Rea

ctan

ce (o

hms)

Time (s)

Va Vb Vc Ia Ib Ic XTF

25© 2007 Electric Power Research Institute, Inc. All rights reserved.

Key Application – Fault Location

Measurements

Probable fault locations

Known fault

location

2626

FaultFault location location nextnext stepssteps

Collaboration between EPRI and Hydro-Québec (2 mirror projects):

Hydro-Quebec will expand its actual fault location project by implementing fault current measurement in a HQ substation and using EPRI's concept through PQView.EPRI will find a partner among US utilities to implement Hydro-Québec's fault location system as a demonstration project

Hydro-Québec continues to improve its faultlocation system (Cost of sensors and telecommunication, MILE predictivecapabilities…)

2727

Underground Vault

2828

Underground DA programUnderground DA program

Justification: improvedowntown MontrealSAIDI

Completed in 2006 (~ 100 remote controlledunderground switches)

Optical fiber is usedfor telecommunication

Project to extend data acquisition for the underground system (system of the future)

3ph Transformers 1Ph Transformer

Sectionnalizing

Underground transformer vault

3030

Teaching installation, 1 st. prototype

RTU

Connexion box

Underground remote control switchWater levelindicator

Optical fibers

3131

Underground Underground VaultVault of the futureof the future

First stage of the project (defining the needs)From 8 potential benefits, 2 were selected

Transformers and underground cable overloadTeledetection of thermal anomalies

3232

Underground Underground VaultVault -- TodayToday

Underground vaultToday (Year 2000)

Transformers :

Medium voltage cables3ø, 500 or 750 MCM Al, 25 kV,

XLPE, cn Cu1ø, 3/0 Al, XLPE, Nc Cu

MV connections :

ComponentsComponents

3333

Underground vaultTomorrow

Transformers :

Medium voltage lines and Sectionnalizer :

MV connections :

- Overload- Water level- MV voltage - LV Protection opération

- Fault detection- Feeders currents-Overload

Data acquisition systemLoad profile- Follow-up of thermal evolution

- Detection et teleindication of thermal anomaly

- Water presence- Waterpump monitoring

Underground Underground VaultVault of the futureof the futureTelemonitoringTelemonitoring

ComponentsComponents

3434

PQ data from Distribution substations

3535

PQ data PQ data fromfrom Distribution Distribution substationssubstations

Hydro-Québec's substations belong to the transmission company (TransÉnergie)Substations PQ monitoring equipment selected in 2006: ION 8600 / 8800 from Schneider-PML

One PQ meter per MV busbar or Power Transformer

More than 50 meters installed by the end of this year, (57 planned for 2008)Joint working group (HQ Distribution / TransÉnergie) to optimize the data management (Secure Data access, Data architecture and software, standard reports, specific PQ analysis…)

3636

Data management software analysis

3737

DATA Management DATA Management –– SotwareSotware analysisanalysisThe goals are:

Analyze the Software available to manage the distribution equipment (Reclosers, Remote Controlled Switches, Voltage Regulators, Meters…) installed on Hydro-Québec's distribution system:

Precision and accuracy

Compatibility, file format

Ease of use

Gather information to optimize the data management for Hydro-Québec's technical staff

3838

RESULTS RESULTS -- Control, relay & meter software Control, relay & meter software interface characteristicsinterface characteristics

Interface Software

* Test on IED and corresponding software not performed yet

3939

RESULTS RESULTS -- Control, relay & meter software Control, relay & meter software interface characteristicsinterface characteristics

* Test on IED and corresponding software not performed yet

4040

CONCLUSIONS CONCLUSIONS -- Control, relay & meter Control, relay & meter software interface characteristics software interface characteristics

The analysis of the software results in the following conclusions:

Software Interface:

All the different equipments present on the distribution system have their own proprietary software not compatible to each other, making very difficult for distribution engineers and technicians to communicate with the equipments, retrieve and interpret the data.

Most of the software interfaces were found to be user friendly.

Some interfaces are more complex and difficult to use (Versatility).

PQVIEW is the most versatile software so far

Data file format:

Several file formats are used: text, PQDIF, COMTRADE, SQL, etc.

So far, an SQL database has shown great advantages.

4141

CONCLUSIONS CONCLUSIONS -- Control, relay & meter Control, relay & meter precision and accuracy precision and accuracy

Controls Measurement Accuracy and Linearity

The accuracy of controls measurement is acceptable, but the measurements do not fully comply with international standards.

Meter Accuracy and Sampling Rate

The accuracy of meters is higher than that of controls. The meters comply with some of the international standards. Their sampling rate ranges from 128 to 1024. Some of them qualify for class A as defined by IEC 61000-4-30.

4242

Data management Software analysis Data management Software analysis --General conclusionGeneral conclusionData management from today's equipment is possible but it is surely not optimal

There is a need for data integration to reduce cost and improve data acquisition efficiency

This project brought knowledge about present distribution equipment performance and improvements to do in the future (technologies, sensors, standards…) to integrate data acquisition

4343

Distribution Network of the futureDistribution Network of the futureDistributionDistributionTransmissionTransmission

P&PP&P

P&PP&PP&PP&P

P&PP&PP&PP&P

P&PP&P

P&PP&P

P&PP&PP&PP&P P&PP&P

Energy exchange

Architecture IEC 61850Architecture IEC 61850 ResidentialResidential

IndustrialIndustrial

InstitutionalInstitutional

Customers

Collaboration is needed between utilities and manufacturers Collaboration is needed between utilities and manufacturers to define distribution data integration standards to define distribution data integration standards

based on IEC 61850 and CIM standards.based on IEC 61850 and CIM standards.

Distribution system technologies Distribution system technologies (sensors, control cabinet, meters(sensors, control cabinet, meters……) development ) development

and software must be coordinated through standardsand software must be coordinated through standardsto reduce cost and reach a "plug and play" design.to reduce cost and reach a "plug and play" design.

4444

Next steps

4545

Next steps in HydroNext steps in Hydro--QuQuéébec's ADA bec's ADA programprogram

1. Volt and VAR Control• Demonstration project – End 2008

2. Fault location• 2 mirror demonstration projects (one in Québec, one in the US) –

Collaboration with EPRI

3. Underground Vault• Beginning of stage 1

4. PQ Data from Distribution substation• Joint working group (HQ Distribution / TransÉnergie) to optimize the

data management from the PQ monitoring equipment

5. Data management • Software analysis – completed

• Sensors analysis - 2008

4646

HydroHydro--QuQuéébec'sbec's DA/DER test lineDA/DER test lineThe test line has been used for

DA equipment performancesBroadband on Power Line testsPower Quality BenchmarkData management software

In 2008, it will be used forSensors analysisCapacitors testingDER testing

4747

Hydro-Québec's Distribution roadmap

4848

Phase 1

December 2006

Phase 2

June 2007

Phase 3

December 2007

Collecte de l'information

Balisage

Plans d'évolution actuels

Enjeux d'affairesPrincipes directeurs

Élaboration d'une vision

Élaboration du plan d'évolution

Plan d'évolution intégré

Études AnalysesValidation

Élaboration de la vision commune

Développement de la R&D

Homologation d'équipements

Émission d'encadrements

Plans de travail

Convergence

Collecte de l'information

Balisage

Plans d'évolution actuelsPlans d'évolution actuelsPlans d'évolution actuels

Enjeux d'affairesPrincipes directeurs

Élaboration d'une vision

Élaboration du plan d'évolution

Plan d'évolution intégréPlan d'évolution intégré

Études AnalysesValidation

Élaboration de la vision commune

Développement de la R&D

Homologation d'équipements

Émission d'encadrements

Plans de travail

Convergence

Global Roadmap ProcessGlobal Roadmap Process

Benchmarking

Studies,Analyses

Work plans

Integrated development plan

Collection of information

Elaboration of a vision

Elaboration of a shared vision

Elaboration of a development plan

Business driversGuiding principles

Current development plans

CohesionR&D Development

Equipment certificationPublication of standards

4949

HydroHydro--QuQuéébec's Distribution roadmapbec's Distribution roadmap

In 2007 Hydro-Québec started a global roadmap exercise Technology: a contribution to efficiency

Up to now the roadmap confirms that telecommunication technology will impact operation, maintenance and metering for the next 15 years

The general design of both overhead and underground systems should remain the same for the next 15 years

5050

ConclusionConclusionHydro-Québec has started several projects related to Advanced Distribution Automation

Demonstration projects will be launched on Volt and Var Control and Fault location projects in 2008Data management studies will continue in 2008 (PQ data coming from substations and Sensors installed on feeders)

Collaboration is needed between utilities and manufacturers to define distribution data integration standards