epri's xiii annual power switching safety and reliability...

September 14, 2009 EPRI's XIII Annual Power Switching Safety and Reliability Conference

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Distributed GenerationPresented by: Doug Fairchild & Chris Cooper


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Agenda

• Hydro One Overview• The state of DG in the Province of Ontario• Technical Issues• Operational Requirements Overview• Control Room Network Management

System


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Hydro One Overview


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Family of Companies


5

Hydro One Networks

Hydro One Networks

AssetManagement

Engineering &Constructions Grid Ops Customer Ops


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Our Mission


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Where are we?


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Ontario Grid Control Center (OGCC)


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System DetailsStations Transmission - 274Distribution - 1035

Lines/UG Cables500kV - 3,784km230kV - 13,824/50km115kV -10,953/220km 4 to 44kV - 119,800km

CustomersTransmission:Large Direct - 94Local Distribution - 83Generation - 33

Distribution:Customers - 1.3 M

Generators174 (includes 77 OPG)

2007 Peak Demand25,707 MW 28,005 MW (Highest Peak recorded Aug 1, 06)


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Eastern Inter Ties

New York 1,700-2,050 MW in 1,700-2,350 MW out

Ontario

Michigan1,250-1,400 MW in 1,550-

1,700 MW out

Minnesota90 MW in

140 MW out

Quebec1,500 MW in;620 MW out

Manitoba330 MW in;260 MW out


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The State of DG in the Province of Ontario


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Current Supply Mix

As of: 1st Quarter 2009 RESOP Supply Mix


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DG Supply Mix (RESOP)

As of: 1st Quarter 2009

Renewable Energy Standard Offer Program


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DG Connection Process

CIA CIA

Cost EstimateCost Estimate

Design & ConstructDesign & Construct

Init. Consult./FeasibilityInit. Consult./Feasibility

Impact on Distribution System and supply station

How much willit cost?

Design, Construct & Commission

Cost Recovery Agreement

Cost Estimate Agreement

CIA Study Agreement

ConnectConnect Connect

Connection Agreement


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Renewable Generation


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Generator Categories

ConnectionTransmission

TS BusH1 DistributionLDC (Co-op)

Embedded LDC

MeteringNet MeteringWholesale

RetailLoad Displacement

Emergency Back-Up

FuelWind

Hydro ElectricWaste

Bio-fuelSolar

SizeMicroSmall

Mid-SizedLarge


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Ontario Electricity Stakeholders

ExternalOntario GovernmentMinistry of Energy

OEBOPAIESOESA

DevelopersOFA

LDC'sCSA

InternalDistribution System

Development Legal

Engineering and Construction Services

Provincial LinesRegulatory

Metering and SettlementsGrid Operations


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Technical Issues

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TS

Tran

smission

System

Distribution

System

LoadLoad

Load

Load

Generator

Distributed Generation Base Case: No Distributed Generation

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GeneratorTran

smission

System

TS

LoadLoad

Load

Load

Distributed Generation Case 1: Loads > DG

DG

Tran

smission

System

Distribution

System

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Generator

TS

LoadLoad

Load

Load

Distributed Generation Case 2: DG > Load

DG

Tran

smission

System

Distribution

System

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Generator

TS

LoadLoad

Load

Load

Distributed Generation Case 2: DG >> Load, Reach Dx Feeder Thermal Limits

DG DG

Tran

smission

System

Distribution

System

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Generator

TS

LoadLoad

Load

Load

Distributed Generation Case 4: Voltage Fluctuation – Sudden disconnection of DG

Tran

smission

System

Distribution

System

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Generator

TS

LoadLoad

Load

Load

Distributed Generation Case 5: Fault Causes “Islanding” due to Distribution Fault

DG

Supplied by DG Only

Tran

smission

System

Distribution

System

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Generator

TS

LoadLoad

Load

Load

Distributed Generation Case 5: Protection, Control, & Telecom Corrects Islanding

DG

Breaker left open to

protect DG

Tran

smission

System

Distribution

System

Momentary Outage

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Generator

TS

LoadLoad

Load

Load

Distributed Generation Case 6:DG >> Load; Exceed Station Equipment Limits

DG DG

Tran

smission

System

Distribution

System

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Generator

TS

LoadLoad

Load

Load

Distributed Generation Case 6:Exceed Interface Limits

DG DG

Tran

smission

System

Distribution

System


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Operational Requirements


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Telemetry Requirements

Generators > 250 kW’s:• MW• MVAR• Current• Voltage

** As measured at the Point of Common Coupling (PCC)


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Customer Interface Protections

• Over/Under Voltage• Over/Under Frequency• Overcurrent Protection• Distance Protection


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Power Quality

• DG’s are not allowed to actively control the voltage. They currently operate at a fixed power factor.

• Must meet industry standards for:– Flicker– Harmonic Distortion

• PQ meter required – data logged


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Connection Agreement

• Connection Agreement template updated to reflect DG operating requirements;– Real Time Contact– Emergency Switching– Limitations of the Distribution System– Loss of telemetry


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Operational Requirements

• DG must disconnect if the normal (or approved alternate) supply changes. Established at the CIA stage.

• Any temporary feeder parallels using an air break switch requires DG’s to come off-line.

• No automatic re-synchronization unless:– DG has 24 hr contact with ability to disconnect or– Hydro One has remote control of customer LBS

• Lock out auto re-synch. after 15 minutes of loss of supply (voltage/frequency).


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Commissioning

• Customer is responsible to commission their own facilities

• Hydro One is obligated to ensure safe & reliable operation of the distribution system

• The “COVER” provides a documented process to ensure interconnected systems have been verified to operate as designed

COVER – Confirmation of Verification Evidence Report


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Long term Strategy

• Need to develop a long term strategy• Control Room primarily monitors Transmission Assets.• Smart Grid occurs at the Distribution level.• DG is not evenly spread across the province.• How do we grow the control room?• Should we develop both Tx & Dx specific Operators?• Or should our Operators know both systems?• Need for a higher level of service to our DG customers.


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Network Management System

• Display all Generation above 250 kW’s• Real Time Data:

• Analogs• Alarms• Status• Control

• Need for Aggregate DG output per:• Feeder• Station


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EMS Display Template


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Sample EMS Displays


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Thank You

epri's xiii annual power switching safety and reliability...

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