Lou Fusco - PG&E


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Case Study, The Networked Grid 2010

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Lou Fusco - PG&E

  1. 1. 1 The Smart Transmission Grid Lou Fusco Director Engineering and Technology Pacific Gas and Electric Company
  2. 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 2
  3. 3. Balancing Competing Priorities Environmental Sustainability Smart Grid Reasonable Reliable Service Cost 3
  4. 4. A Smart Grid Overlay with intelligence and automation Sense Communicate Compute Control Power Transmission Substations Distribution Consumers Plants Networks Networks 4
  5. 5. A Dynamic Balance Of Resources Renewable Resources Balancing Resources Smart Grid 5
  6. 6. Transmission System Applications Advanced Protection & Remedial Action Scheme Control System (RAS) Substation Automation Substation Modular Protection and Control (MPAC) 6
  7. 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 7
  8. 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 8
  9. 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 9
  10. 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   10
  11. 11. System Architecture Upgraded hardware with backup at remote location AS IS: Obsolete hardware TO BE: Redundancy at single site 11
  12. 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 12
  13. 13. Interactive HMI 13
  14. 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   14
  15. 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 15
  16. 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%) 16
  17. 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 17
  18. 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 18
  19. 19. Legacy Control Center Equipment 19
  20. 20. MPAC Interior 20
  21. 21. MPAC Exterior 21
  22. 22. At PG&E, We Are Committed To Sustainability 22