PNM High-Penetration PV thru Grid Automation & Demand Response

1. PNM High-Penetration PV thru Grid Automation & Demand Response Jonathan Hawkins Manager, Electric Distribution Standards PNM Grid-InterOp 2009 Denver, CO Nov 17-19, 2009

2. High-Penetration PV thru Grid Automation & Demand Response UC4 UC2 UC1 UC3 • Changes to existing architecture (if applicable) • Interface implications to legacy systems • Architecture Considerations for Emerging/changing requirements • Improved Benefits from Architecture Changes • Overall Project Lessons Learned (3-5 Slides) • Topics could be wide ranging (project planning, resources, stimulus implications, software integration, hardware installation, customer acceptance, etc.) • What surprised you? What information would member utilities find interesting? • Q&A

3. PNM’s Smart Grid – Additions to existing Architecture • Changes to existing architecture (if applicable) • Interface implications to legacy systems • Architecture Considerations for Emerging/changing requirements • Improved Benefits from Architecture Changes • Overall Project Lessons Learned (3-5 Slides) • Topics could be wide ranging (project planning, resources, stimulus implications, software integration, hardware installation, customer acceptance, etc.) • What surprised you? What information would member utilities find interesting? • Q&A

4. Interface implications to legacy systems • Communications Protocols – IEC61850/DNP3 • Cyber-security Standards • IEC61850 interface to Home Area Network (via inverter interface) and commercial building’s energy management system (e.g. BACNet) • Distributed Energy Resource response translation through the architecture to billing system • New customer contracts – e.g. demand response, renewables through AMI, penalties for opt-out, strict measurement of renewable energy certificates (RECs)

5. Considerations for emerging/changing requirements • Communication and Cyber-security Standards still evolving • Specifying multiple protocols where possible and cost-effective • IEC61850 and DNP3 • Zigbee, Homeplug, Smart Energy Profile, 6LoWPAN • Concerns of multiple profiles • Protocol interfaces (translation) • Latency requirements (does an alternate protocol dictate a higher latency) • Bandwidth requirements • Varying communication time requirements (e.g. 1 sec. control data vs. 15 min. pricing data)

6. Improved Benefits from Architecture Changes • Economic • Start with Ability to send “real-time” prices • Price components could be • Distribution grid loading • Day-ahead load Forecast • Wholesale prices (regional hub based) • Carbon pricing • Target “Firmed up” renewables (Dispatchable) • Reliability • Ability to unload feeders • Prevent overuse of equipment/extend equipment life (e.g. LTCs, Cap Banks) • Ability to “right size” feeder equipment • Back office efficiency – multiple systems able to use data

7. Overall Project Lessons Learned • Modeling will be critical • Little is known or tested on battery control algorithms; DG placed at end of feeder vs. beginning of feeder could be completely different • Models need to be calibrated on the front end for acceptance - GridLAB D and OpenDSS modeling has started • Lots of data will be needed to validate front and back ends of modeling effort • Functional/org structure issues have to be raised as SG architecture is developed • Groups/functions will need to be in place and staffed that don’t exist now • These are costs that have to be identified along with equipment costs • Technology gaps and incumbent architecture need to be displayed to industry from a non-silo’d perspective • Architecture needs to incorporate NIST and align with other demo projects

8. Thank You! Questions?