1. Smart Grid Projects NSTAR
Larry Gelbien
New England Restructuring RoundTable
December 4, 2009

2. AGENDA Overview of Three Smart Grid Projects Questions
Grid Self-Healing Project
Urban Grid Monitoring and Renewables Integration Project
AMR Based Dynamic Pricing Project
Questions

3. Grid Self-Healing Project DOE ARRA Deployment Project

4. Automated Sectionalizing Unit Program
Cumulative Number of Averted Sustained Customer Outages Due to ASU Operations: Through 10/31/09
Slide Updated November 9, 2009 4 4

5. Top Decile Reliability Restoration 2006 2007 2008 2005 YTD 2009 10.9
Avg. months between
interruptions
Avg. time to restore
service
2006
2007
2008
2005
YTD
2009
10.9
12.4
9.8
16.1
11.8
Our successes reflect the robust Performance Management Process at NSTAR.
We track, measure and report on several critical performance metrics each and every month.
As you can see – our electric system reliability is outstanding and when we experience an outage - we’re able to restore power quickly. These performance results are in the top decile in our industry
And these results have continued through September 2009, with reliability at 16 months between interruptions and restoration at about 78 minutes.
2006
2007
2008
2005
YTD
2009
77.5
69.5
76.6
94.4
78.2 5 5

6. Smart Grid – Distribution Automation
Over 1,300 SCADA Switches with over 7,500 smart sensors installed through the service
40 to 60 new devices with 120 additional smart sensors annually 6 6

7. Smart Switch Equipment7 7

8. “Self-Healing” Distribution Grid
With State-of-the-Art Technology
Electric delivery network using modern sensing, communications, and information processing based on digital technologies
Microprocessor-based measurement and control using remote sensors
Current, voltage, KVA, temperature
Circuit self-healing implementation (Auto-Restoration): 900 circuits
Supervisory controlled overhead and underground switches with voltage and current sensors: 220 switches
Interoperability standards using PI interface
SCADA interface to recloser control cabinet: 20 reclosers 8 8

9. Three Operational Modes
Mode 1: “Supervisory” mode
Leverages remote control of switches
Operator controlled sequences
Mode 2: “Operational Acknowledgement” mode
Computer-simulated restoration sequences
Operator validation and execution
Mode 3: “Self-Healing” mode
Computer-determined restoration sequences
No human intervention 9

10. NSTAR Grid Improvement – Example of how ASUs work10 10

11. Self-Healing Auto-Restoration11 11

12. GWAC Interoperability Checklist for Project
--Short discussion of how the approach to DA has changed to provide more interoperability and flexibility
--RTU and radio vendors, etc. can be substituted if necessary.
--A quick look at the GWAC Checklist document will be useful 12 12

13. DOE Funding Approved
$20 million deployment project with % DOE funded
NSTAR to fund 50% as capital project
DOE grant agreement to be executed

14. Urban Grid Monitoring and Renewables Integration Enablers to Test Distributed Resource Integration14

15. Project Objectives Improve visibility into secondary area network grid
Deploy sensors on the underground secondary network methodology
Refine methods suitable to scale broadly across urban areas nationwide
Develop model to safely examine small inverter-based distributed resource integration
Solar PV integration from downtown customers
Potential for integration anywhere on the test grid
Pave the way for other, inverter-based DER in the future
Received DOE Smart Grid demonstration grant, pending DPU approval 15

16. Demonstration Grid Location (Shown in Red)16 16

17. Functionality Deployed in “Layered” Approach
Layers provide the data collection, monitoring, and analysis required for safely testing distributed resource integration 17 17

18. Metering and Analysis
Distributed resource interconnection on secondary networks
IEEE 1547 examined
Approach submitted for comment at August 2009 IEEE meeting
Additional metering capability
kWh smart metering on customers with PV integration
Enhanced feeder data metering including V & A phase info
Customer PV interconnection
Power flow monitored
Remotely controlled to disconnect on unsafe condition
Engineering analysis
All sensor data to be collected at Collection Server
Information forwarded to SCADA system and plant information system for Engineering, Operations, and Planning access 18

19. Project Topology View 19 19

20. Key Questions to be Answered
What significant deployment and installation challenges were encountered?
What is the percent of load from participating customers?
From PV vs. other sources
How effective was the mixed data collection methodology?
What is the frequency of disconnect due to grid stability concerns?
Will a higher percent of minor-node be effective in the future?
How durable is the sensing equipment, especially minor-nodes? 20

21. AMR–Based Dynamic Pricing Project
Pilot requirements
Cover at least 2,750 customers (0.25 % of subscribers)
Integrated two-way communications
Smart meters
Real-time measurements and communications
Embedded automated load management
Remote monitoring and operation of distribution system
Time-of-use or hourly pricing
Rate treatment of incremental program costs
Minimum 5% load reduction (peak and average)
Received DOE Smart Grid demonstration grant, pending DPU approval 21 21

22. Tendril Transport (gateway)
Consumer Behavior: Provide Accurate Information to Make Informed Decisions
Load Control
Pricing Options
Energy Efficiency (CFL, Load Control, Solar, DG, PHEV)
broadband
Tendril Insight
(in-home display)
Tendril Set-Point
(thermostat)
Tendril Transport (gateway)
Tendril Volt (outlet)
Tendril Mobile 22 22

23. Near Real-Time Information for Customers and Utilities
Communication Options
Least Cost Options
Minimize Stranded Costs
Mesh
AMR/AMI over Customer’s Broadband Service
Broadband over Power Line
Cellular
Placed here as this seemed a good point to discuss the wide range of communications options 23 23

24. QUESTIONS?