public utilities board meeting january 18, · pdf file · 2013-03-16public...
TRANSCRIPT
Working Smarter Distribution Automation Program Public Utilities Board Meeting January 18, 2013
Working Smarter
RPU Strategic Plan
Three-Year Goal Maximize the use of technology to improve utility operations Specifically – present to Board for Approval an R&D Electric Distribution Automation Project
Ten-Year Goal Employ state-of-the-art technology to maximize reliability and customer service
What We Are Doing Now Substation Automation System (SAS)
Digital System Protection Event Capture and Evaluation
Supervisory Control and Data Acquisition (SCADA) Upgrade Project in progress
Expanding Fiber Infrastructure Some Remotely Automated Devices GIS Mapping Thermal Imaging
Outage Response Procedure
Event on the Electric Grid Troubleman patrols (drives) circuit Customer calls help to locate area Field Switching if possible Troubleman fixes problem, or; Call in crew Crew makes repairs Service is restored
Measuring Reliability (IEEE Indices)
SAIDI (System Average Interruption Duration Index) Average interruption duration (in minutes), for customers served during a 12-month period Goal – 50 minutes Actual 2012 – 42.49 minutes Actual 2011 – 52.93 minutes
SAIFI (System Average Interruption Frequency Index) Average number of times that a customer is interrupted during a 12-month period Goal – 1.15 interruptions Actual 2012 – 0.63 interruptions Actual 2011 – 0.51 interruptions
Distribution Automation
Allows RPU to: Use technology to reduce/minimize outages Utilize tools for asset management
diagnostics Maximize equipment value and service life Avoid equipment failure Capital savings via proactive vs. reactive
equipment replacement
Effective use of fiscal resources Efficient use of human resources
Distribution Automation Benefits Detail information to System Dispatchers Determine problem faster Decrease number of customers affected Reduce unnecessary stress to other equip. Improve customer communication Improve reliability indices
Monitoring and Diagnostic Tools Identify high risk circuits Obtain Load Profiles and Direction of Fault Develop heads-up dashboard displays Perform real time monitoring
Intel for cables and overhead lines Distribution IQ for pad-mounted equipment Monitors for SF6, dissolved gas, temperature IQ for substation transformers
Proposed Areas and Lab Location
Circuit descriptions:
Circuit Area of Service OH or UG
1213 Residential peripheral to UCR OH
1311 Downtown UG/OH
1217 Victoria OH/UG
1287 La Sierra/Arlanza OH
Automation Test/Training Lab – Proposed in Mission Square, 4th Floor
La Colina Substation
Riverside Substation
Harvey Lynn Substation
Circuit 1213
Circuit 1311
Circuit 1287
Circuit 1217
Proposed Areas For Initial Focus
Typical Circuit
Substation #1
Pole Switch A
Pole Switch B
Tie Switch C
Substation #2
Pole Switch D
8/30/2012 Outage – Circuit 1213
Existing enclosure and switch
Proposed communication pedestal and switch controller
Circuit 1311 – Downtown (SE7774) UG Application
Automation Test/Training Lab Proposed location – Mission Square, 4th Floor
Sole Source Procurement
Specialized Equipment
Utilize Several (7) Vendors/Manufacturers
Established track record of success in distribution automation applications
Different Equipment at each location
Allow Evaluation of Technologies
Evaluating Program Results
Ease of installation
Compatibility with existing equipment
Data gathering – (how does this fit in with broader effort to evaluate automation system wide?)
Operational attributes
Staff training requirements
Impact on Reliability Indices
Recommendation to Board
That the Board of Public Utilities: 1. Approve the estimated capital expenditure
of $960,000 for Work Order 1309568 to procure and install automated controllers, associated communication equipment, and automation test/train lab apparatus; and
2. Authorize the Purchasing Services Manager to award Purchase Orders to ABB, Cooper, G&W, GridSense, S&C, Schweitzer, and Siemens not-to-exceed $220,000 for each equipment purchase.