Distributed Generation Presented by: Doug Fairchild & Chris Cooper 1
Agenda Hydro One Overview The state of DG in the Province of Ontario Technical Issues Operational Requirements Overview Control Room Network Management System 2
Hydro One Overview 3
Family of Companies 4
Hydro One Networks Hydro One Networks Asset Management Engineering & Constructions Grid Ops Customer Ops 5
Our Mission 6
Where are we? 7
Ontario Grid Control Center (OGCC) 8
System Details Stations Transmission - 274 Distribution - 1035 Lines/UG Cables 500kV - 3,784km 230kV - 13,824/50km 115kV -10,953/220km 4 to 44kV - 119,800km Customers Transmission: Large Direct - 94 Local Distribution - 83 Generation - 33 Distribution: Customers - 1.3 M Generators 174 (includes 77 OPG) 2007 Peak Demand 25,707 MW 28,005 MW (Highest Peak recorded Aug 1, 06) 9
Eastern Inter Ties Manitoba 330 MW in; 260 MW out Ontario Minnesota 90 MW in 140 MW out Quebec 1,500 MW in; 620 MW out Michigan 1,250-1,400 MW in 1,550-1,700 MW out New York 1,700-2,050 MW in 1,700-2,350 MW out 10
The State of DG in the Province of Ontario 11
Current Supply Mix As of: 1 st Quarter 2009 RESOP Supply Mix 12
DG Supply Mix (RESOP) Renewable Energy Standard Offer Program As of: 1 st Quarter 2009 13
DG Connection Process Init. Consult./Feasibility CIA Study Agreement CIA Cost Estimate Impact on Distribution System and supply station Cost Estimate Agreement How much will it cost? Cost Recovery Agreement Design & Construct Design, Construct & Commission Connection Agreement Connect Connect 14
Renewable Generation 15
Generator Categories Metering Net Metering Wholesale Retail Displacement Emergency Back-Up Fuel Wind Hydro Electric Waste Bio-fuel Solar Size Micro Small Mid-Sized Large Connection Transmission TS Bus H1 Distribution LDC (Co-op) Embedded LDC 16
Ontario Electricity Stakeholders External Ontario Government Ministry of Energy OEB OPA IESO ESA Developers OFA LDC's CSA Internal Distribution System Development Legal Engineering and Construction Services Provincial Lines Regulatory Metering and Settlements Grid Operations 17
Technical Issues 18
Distributed Generation Base Case: No Distributed Generation Transmission System Generator TS Distribution System 19
Distributed Generation Case 1: s > DG Generator TS DG 20 Distribution System Transmission System System
Distribution System Transmission System Distributed Generation Case 2: DG > Generator TS DG 21
Distributed Generation Case 2: DG >>, Reach Dx Feeder Thermal Limits Transmission System Generator TS DG DG Distribution System 22
Distributed Generation Case 4: Voltage Fluctuation Sudden disconnection of DG Transmission System Generator TS Distribution System 23
Distributed Generation Case 5: Fault Causes Islanding due to Distribution Fault Transmission System Generator TS DG Distribution System Supplied by DG Only 24
Distributed Generation Case 5: Protection, Control, & Telecom Corrects Islanding Transmission System Generator TS DG Breaker left open to protect DG Distribution System Momentary Outage 25
Distributed Generation Case 6: DG >> ; Exceed Station Equipment Limits Transmission System Generator TS DG DG Distribution System 26
Distributed Generation Case 6: Exceed Interface Limits Transmission System Generator TS DG DG Distribution System 27
Operational Requirements 28
Telemetry Requirements Generators > 250 kw s: MW MVAR Current Voltage ** As measured at the Point of Common Coupling (PCC) 29
Customer Interface Protections Over/Under Voltage Over/Under Frequency Overcurrent Protection Distance Protection 30
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 31
Connection Agreement Connection Agreement template updated to reflect DG operating requirements; Real Time Contact Emergency Switching Limitations of the Distribution System Loss of telemetry 32
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). 33
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 34
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. 35
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 36
EMS Display Template 37
Sample EMS Displays 38
Thank You 39