Case Study, The Networked Grid 2010

1. 1
The Smart Transmission Grid
Lou Fusco
Director
Engineering and Technology
Pacific Gas and Electric Company

2. Pacific Gas and Electric Company
Energy services to 15 MM people (1 in 21 Americans)
• 5.1 MM Electric customer accounts
• 4.3 MM Natural Gas customer accounts
70,000 square miles with diverse topography
20,000 employees
A regulated investor-owned utility
Ranked the greenest utility in the United States
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3. Balancing Competing Priorities
Environmental
Sustainability
Smart Grid Reasonable
Reliable Service Cost 3

4. A Smart Grid
Overlay with intelligence and automation
Sense Communicate Compute Control
Power Transmission Substations Distribution Consumers
Plants Networks Networks
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5. A Dynamic Balance Of Resources
Renewable Resources Balancing Resources
Smart Grid
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6. Transmission System Applications
Advanced Protection & Remedial Action Scheme
Control System (RAS)
Substation Automation Substation Modular
Protection and Control
(MPAC)
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7. Pacific Intertie – AC RAS
Pacific Intertie is a critical infrastructure for stabilizing the
Western North American power grid
• Three AC lines and one HVDC line
• Largest single electricity transmission program in the United States
• Capable of transmitting up to 7,900 MW: 4,800 MW on AC; 3,100
MW on DC
AC Intertie Remedial Action Scheme (RAS)
• Collects data in the substation
• Modulates data onto multiple carriers
• Transmits data to central location
• Demodulates data
• Connects data to two controllers
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8. Pacific Intertie RAS
Western Electric
Coordinating Council
• Trips “Armed” Generation
• Insert “Chief Joe” Braking Resistor
• Suspends Automatic Generation Control
• Reactive Devices capacitors and reactors
• Trips Interties
• Trips “Pump” load
• Trips “Firm” load
Initiates NE/SE
Separation
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9. RAS: An Effective But Aging System
Today’s System
Advantages of new devices & digital
In operation since late 1980’s
paths Include:
Very high reliability/availability >99.995
• Synchronized RAS systems
Enables significant increase in grid
• Same data is sent to two places
transfer limit capability (approx 3600
MW)
• Sustained stable RAS performance
Protects WECC area from widespread
• Minimized substation design work and
system outages, system collapse and
maintenance
total blackouts
• Obsolescence of the substation
devices is systematic and uniform
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10. New RAS Requirements
Capture the real-time power system state: Flows, frequency,
angle, temperature, wind speed, and statuses
Minimize use of transducers to gain accuracy
Transmit measured values to multiple remote locations
Receive and transmit to remote sites, and execute any
control actions determined by the controller
Have power system information available at a monitored
location for future activation
Perform automatic self diagnostics
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11. System Architecture
Upgraded hardware with backup at remote location
AS IS: Obsolete hardware TO BE: Redundancy at single site
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12. Messaged Versus Hardwired
Advantages:
• Replace local control wiring with IED relays and data
communications via LANs
• No need for periodic testing (devices communicate
continuously)
• Minimizes hardware installation
• Saves space
• Provides almost endless expansion capabilities
• No need to update wiring diagrams
• No contacts, debounce filtering, not prone to noise
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13. Interactive HMI
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14. Success
New C&D Systems operational 4/29/2010
Project started in June 2006
Project cost $12M under budget
No injuries or mis-operations
RAS A&B systems in San Francisco scheduled for
replacement
Extensive testing performed
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15. Substation Automation
Need for a cost effective, state of the
art, replacement strategy for
substation automation and protection
Provide interface to a consolidated
grid control center, operated by an
Energy Management System
Modular Protection Automation and
Control (MPAC) created to implement
our vision
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16. MPAC Success
Deployed MPAC since 2005 with ~50 buildings on sites
Plan to install another 60-70 in the next 5-6 years as part of the
transmission system modernization efforts
Key metrics:
1. Cost saving (20% reduction)
2. Procurement schedule (40% reduction)
3. Delivery schedule (38% reduction)
4. Terminal clearance schedule (60% reduction)
5. Project schedule to Operational (23%)
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17. MPAC Benefits
Improved Reliability:
Replace deficient protection schemes
Improve visibility, controllability and accuracy for the operators
Improve ability to remotely control equipment to speed restoration
Improved Efficiency:
Replace obsolete control room equipment
Reduced need to clear relay terminals for maintenance
Improve major equipment maintenance triggers
Replace equipment on a wholesale approach
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18. MPAC Benefits
Cost Savings:
Reduced cost to engineer, construct, and maintain
Reduce protection scheme maintenance
Improved Safety and Environmental Performance:
Provide remote control
Minimize exposure to employees on existing panels and buildings
Improved Compliance:
Improved ability to evaluate and analysis system events
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19. Legacy Control Center Equipment
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20. MPAC Interior
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21. MPAC Exterior
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22. At PG&E,
We Are Committed To Sustainability
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