1. Irvine Smart Grid Demonstration Bob Yinger | Southern California Edison October 27, 2015

2. Objective Demonstrate a cross section of what the modernized grid might look like by 2020. Smart Energy Customer Solutions Next-Generation Distribution System Interoperability and Cybersecurity Workforce of the Future Demonstration Areas

3. Project Locations University of California, Irvine, CA MacArthur substation, Newport Beach, CA The site is typical of some heavily populated areas of Southern California in climate, topography, environmental concerns, and other public policy issues.

4. Key Dates Award 12/09 Demo Start 7/1/13 Demo Complete 6/30/15 Cost Project Cost $79.2M DOE ARRA Funds $39.6M SCE (in-kind) $26.9M Partners $12.7M

5. Smart Energy Customer Solutions Zero Net Energy Homes Upgraded home energy efficiency Installed PV generation and home/block storage Installed and tested home area network with customer interfaces Tested demand response methods Determined ZNE scores Solar Car Shade Installed 48 kW PV, 100 kW/100 kWh storage, 20 EVSEs Tested use of battery and PV to charge electric vehicles without grid impact Tested different modes of battery/PV operation

6. Zero Net Energy Performance Performance by ZNE Measure Homes Achieving ZNE, by Method 0/9 3/95/9 Average Performance, by Method Performance Across Homes ZNE Home TDV Method TDV = Time Dependent Valuation Simulated

7. EVSE Usage ZNE Avg. Home Total Usage Solar PV Generation RESU Net Usage ZNE Avg. Home Net Usage Home Load With Energy StorageWithout Energy Storage

8. Smart Energy Customer Solutions Worked wellDid not work wellNext steps 1. Energy storage can shift loads, level demand, and provide backup power 2. 3 of 9 homes achieved ZNE under the TDV method 3. Solar PV and LED lighting had the largest impacts 1. HAN communications for demand response needs improvement 2. Sub-optimized energy storage hurts ZNE under TDV 3. Smart appliances have limited DR potential and low customer value 1. Collaborate with DR stakeholders to improve communications and interoperability for key loads 2. Monitor and control a larger number of DERs to resolve grid challenges

9. Next-Generation Distribution System Distribution Circuit Constraint Management Installed 2 MW/ 500 kWh battery on distribution feeder Distribution Volt/VAR Control Installed centralized volt/VAR controls on one substation bus Self-healing Distribution Circuits Installed 4 URCIs and wireless peer-to-peer comm system Used IEC 61850 GOOSE between switches and substation DER Performance Developed algorithm to independently verify operational performance of DER at a substation without individual monitoring

10. Distribution Volt/VAR Control Reduce average consumer voltage in order to decrease associated energy use and optimize VAR flow at the substation transformer bank Reduced voltage by 1.6% which saved 2.5% of energy usage after temperature adjustment

11. Worked wellDid not work wellNext steps 1. DVVC can provide energy savings of 1% to 4% depending on the type of circuit 2. 2 MW battery operated as intended to reduce peak loading on a 12 kV distribution circuit 1. The low-latency field area network (FAN) was unreliable 2. Project battery systems were early in the development cycle (Required multiple shutdowns for repair) 3. Siting challenges – equipment and site aesthetics is very important 1. Implement wide-scale deployment of DVVC 2. Evaluate smart inverters and next generation FAN capabilities in upcoming demos 3. Continue to work with energy storage vendors to resolve operational challenges Next Generation Distribution System

12. Interoperability and Cybersecurity Secure Energy Net Developed method of organizing data from multiple sources so it can be used for control and analysis Implemented advanced cybersecurity for devices in the field and substation Substation Automation version 3 (SA3) Implemented IEC 61850 for data exchange and substation configuration Implemented gateway in substation to interface with field area network, substation controls and SCADA system

13. Interoperability and Cybersecurity Demonstrated Security / Access Control Access management Active monitoring/ notification Configuration Management Auto-configuration w/IEC 61850 Active monitoring of configuration System Operation Networked architecture with routable protocols and distributed processing Communications with field equipment via substation gateway for volt/VAR and URCI systems

14. Interoperability and Cybersecurity Worked wellDid not work wellNext steps 1. SA3 successfully demonstrated that an HMI can be fully configured in minutes, instead of weeks 2. SA3 Substation Gateway proved the viability of automated: Substation configurations Change of passwords Retrieval of relay fault files 1. SCE needed to assume system integrator role 2. Needed more consistent vendor adoption of IEC 61850 3. Cybersecurity standards are still emerging 1. Implement SA3 as a standard for substations 2. Work with vendors and standards development organizations for standards updates 3. Expand substation gateway functionality to satisfy NERC CIP v5 requirements

15. Workforce of the Future Identified and developed the training necessary to support the demonstration of ISGD technologies Assessed potential organizational implications of ISGD technologies

16. Workforce Training Accomplished Assessed skills necessary to perform the work Designed the curriculum and materials Implemented training in classroom and provided an online training tool 16

17. Workforce of the Future Worked wellNext steps 1. A dedicated IT team embedded at AT for cross-functional design team collaboration 2. Workforce training – both in- person and on-demand computer-based training, for impacted personnel 3. Skills gap assessment approach for future workforce needs 1. Conducting workforce strategy project as part of SCE’s grid modernization effort

18. Next Steps Grid Modernization Distribution Resources Plan describes how DER will be integrated Investment Plan describes infrastructure upgrades necessary Preferred Resources Pilot Use preferred resources to meet forecasted electricity growth in the PRP region These resources include: renewable generation, storage, demand response and energy efficiency IGP Area PRP Area Integrated Grid Project Demo controls needed to operate the distribution grid with high penetrations of DER Demo use of DER to optimize the distribution grid Pilot new Field Area Network

19. Bob Yinger Consulting Engineer Advanced Technology Southern California Edison robert.yinger@sce.com