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.