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The Smart Transmission Grid

Pacific Gas and Electric Company

Lou Fusco Director

Engineering and Technology

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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

Pacific Gas and Electric Company

3 Reliable Service

Reasonable Cost

Smart Grid

Environmental Sustainability

Balancing Competing Priorities

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A Smart Grid

Power Plants

Transmission Networks

Substations Distribution Networks

Consumers

Overlay with intelligence and automation

Sense Communicate Compute Control

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A Dynamic Balance Of Resources

Renewable Resources Balancing Resources

Smart Grid

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Transmission System Applications

Advanced Protection & Control System

Remedial Action Scheme (RAS)

Substation Automation Substation Modular Protection and Control (MPAC)

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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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Pacific Intertie RAS

•  Trips “Armed” Generation

•  Trips Interties

•  Insert “Chief Joe” Braking Resistor

•  Suspends Automatic Generation Control

•  Reactive Devices capacitors and reactors

•  Trips “Firm” load

•  Trips “Pump” load

Initiates NE/SE Separation

Western Electric Coordinating Council

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RAS: An Effective But Aging System

 In operation since late 1980’s

 Very high reliability/availability >99.995

 Enables significant increase in grid transfer limit capability (approx 3600 MW)

 Protects WECC area from widespread system outages, system collapse and total blackouts

 Advantages of new devices & digital paths Include:

•  Synchronized RAS systems

•  Same data is sent to two places

•  Sustained stable RAS performance

•  Minimized substation design work and maintenance

•  Obsolescence of the substation devices is systematic and uniform

Today’s System

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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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System Architecture

Upgraded hardware with backup at remote location

AS IS: Obsolete hardware TO BE: Redundancy at single site

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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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Interactive HMI

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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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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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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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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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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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Legacy Control Center Equipment

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MPAC Interior

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MPAC Exterior

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At PG&E, We Are Committed To Sustainability