Transcript Raab Subcommittee Update Draft

MA DPU Electric Grid Modernization
Working Group
Reports From Subcommittees
Steering Committee Meeting #2
February 5, 2013
Dr. Jonathan Raab, Raab Associates
Customer-Facing Subcommittee
Mtg. #1 Agenda (1/9/13)
• Briefing on Time Varying Rates, Metering, and
Customer-Facing Regulatory Policies and MA Utility
Pilots
– NSTAR-- Doug Horton, NSTAR & Stuart Schare, Navigant
Consulting; GRID--Peter Zschokke; & Unitil--Justin Eisfeller
• Time-Varying Rates
– Subcommittee View Sharing and Discussion
• Metering/Data Communications
– Speakers: Itron Smart Grid Solutions: Bruce Husta; AvCom
Corporation: Fred Avila; & Sentinel Works: Jim Hirni
• Regulatory Policies
• Subcommittee View Sharing and Discussion
2
Unitil: Pilot Program Results
3
3
Preliminary Findings
NSTAR Preliminary Results: Load reductions during summer
events vary with the rate and technology
Average Load Reduction (kW)
0.9
0.8
0.7
0.6
0.5
0.4
•
0.3
0.2
•
0.1
•
0.0
Peak Time TOU/CPP +
Rebate
LC (n=309)
(n=349)
TOU/CPP
(n=868)
Peak Time Rebate : Group 2
TOU/CPP + LC: Group 3
TOU/CPP: Group 4
Tech. Only: Group 1
Tech. Only
(n=903)
Automated load control via
thermostats achieves
reductions of 0.7 – 0.8 kW
CPP rate without thermostats
saves ~0.2 kW
Technology group shows
savings, but negligible
* Findings based on two events in
Summer 2012, with simple baseline
load estimation
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4
Pilot Evaluation Timeline
Pilot
Kick-off
Soft
Launch
Pilot
Start
Metrics &
Benefits
Report
Official
DOE
Technical
Performance
Report #1
Interim Report to
DPU
Metrics &
Benefits
Report
End of
Pilot
Official
DOE
Technical
Performance
Report #2
Final Report
to DPU
24 months
Summer
2010
January
2012
September
2012
Winter 2013
Summer
2013
December
2013
Spring 2014
• NSTAR Pilot will run through 12/31/2013 with the final
evaluation to US DOE and MA DPU due April 2014.
5
5
NGRID: Customer Choices
New Rates
Hourly Pricing Program (HPP)
Critical Peak Pricing (CPP)
Peak Time Rebate (PTR)
In Home
Small Business
6
Level 2
6
NGRID: Results To Date
• Early Field Trial (EFT) meters in place since March 2012
– 5,000 meters
– Tested communications
– Tested reading of meter data
– 299 customers opted out of meter (5.97%)
• Remaining 10,000 meters scheduled in service by May 31, 2013
• Pilot start date scheduled for January 1, 2014
• Provides 2 years of baseline data for summer use for 5,000 customers and
one year for 10,000 meters
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8
Is Hybrid Drive-by or AMR Fixed Network a
Realistic Alternative [to AMI]?
(Software/HAN or ChoiceConnect)
•
•
•
•
•
Allows customer interaction
Allows appliance control
Interval data for flexible pricing (TOU, RTP, CPP, etc.)
On demand reads
Realistic additional cost
AvCom Presentation
9
Customer-Facing Subcommittee
Mtg. #2 Draft Agenda (2/26/13)
•
Alternative Metering Scenarios, Functions, Costs for Massachusetts
– Presentation of Subcommittee’s working group on scenarios, functions, & costs
– Utility current meters and meter practices
•
Time-Varying Rates (Subcommittee View Sharing and Discussion)
– What opportunities will time varying rates enable, and how essential are they to developing a
truly modern electric grid?
– What time varying rate options hold the most promise for MA and why?
– Should basic service be structured as time varying rate(s)? What about T&D rates?
– What do competitive suppliers need to be able to effectively offer time varying rate options?
•
Principles and Regulatory Policies for Time Varying Rates and Advanced Metering
– -Brief Presentation on Potential Principles—Barbara Alexander, Consumer Affairs Consultant
to MA AG
– Readings from NASUCA and Faruqui
– What principles should be considered around time varying rates and meters, including any
recommended consumer protections?
– What is the appropriate pace for implementation of customer-facing grid modernization?
– What regulatory policies should the group consider?
•
Planning for Final Two Subcommittee Meetings
10
Grid-Facing Subcommittee
Mtg. #1 Agenda (1/14/13)
• Briefing Grid-Facing Options and Opportunities
– David Malkin, GE
• Successful Grid-Facing Modernization—10-20 Years from
Now
– Utilities: Jennifer Schilling & Larry Gelbien, NU; Chris Kelly,
NGRID
– Clean Energy Coalition: Ram Rao, Ambient
• Utility Planning and Decisionmaking on Grid-Facing
Investments
– NGRID--Chris Kelly; NU--Larry Gelbien; & Unitil--Kevin
Sprague
• Subcommittee View Sharing and Discussion: Grid-Facing
Modernization
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Grid modernization maturity levels
Apparatus………..Physical grid devices
Protection…………Devices to reduce injury or equipment damage
Monitoring...........Maintaining safety, reliability & quality
Metering……………Load management, billing, & system stability
Control………………Operating apparatus & control of power flows
SCADA……………….Supervisory Control And Data Acquisition
Automation………Automatically monitoring & controlling devices
Optimization…….Improving economics, efficiency, reliability & safety
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Technology taxonomy… DOE’s
view
Benefits
Smart Grid Technology Applications
Consumer-Based
Demand
Management
Programs (AMIEnabled)
• Time-based pricing
• Customer devices
(information and
control systems)
• Direct load control
(does not require
AMI)
Capital expenditure reduction
– enhanced utilization of G,T
& D assets
✔
Energy use reduction
✔
Advanced
Fault Location,
Metering
Isolation and
Infrastructure
Service
(AMI) Applied to Restoration
Operations
• Meter services
•
• Outage management
• Volt-VAR
•
management
•
• Tamper detection
• Back-Office systems
support (e.g., billing
and customer
service)
Automated feeder
switching
Fault location
AMI and outage
management
✔
Equipment
Health
Monitoring
• Condition-based
maintenance
• Stress reduction
on equipment
✔
✔
✔
Reliability improvements
✔
✔
✔
O&M cost savings
✔
✔
✔
Reduced electricity costs to
consumers
✔
Lower pollutant emissions
✔
✔
✔
Enhanced system flexibility –
to meet resiliency needs and
accommodate all generation
and demand resources
✔
✔
✔
Improved
Volt/VAR
Management
• Peak demand
reduction
• Conservation
Voltage
Reduction
• Reactive power
compensation
Synchrophasor
Technology
Applications
• Real-time and offline applications
✔
✔
✔
✔
✔
✔
✔
Source: US Department of Energy, Impact of Smart Grid Projects Funded by the Recovery Act of 2009
✔
✔
✔
✔
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Technology taxonomy… NEMA’s
view
1. Smart Grid Solutions
(Grid Resiliency)
• Smart meters /AMI
• Feeder automation
• Fault detection, isolation, restoration
2. Microgrid & Energy Storage Solutions
• Microgrid controllers
• Distributed generation
• Distributed energy storage
3. Hardened Equipment
• Wiring
• Cabling
• Electrical components
4. Back-up Generation
• Diesel or NG generators
• Batteries, fly-wheels, etc.
5. Equipment Repositioning
Source: National Electrical Manufacturers Association,
• Elevating back-up generators
• Substation siting
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NGRID: What will the Customer See…
Now to 5 Years
Urban, Suburban
Reliability Metrics
Pockets of Performance
Develop Value Services
Grid Sensing
Next Generation Automation
Outage Management
Two-way Comms
Converging
Cyber Security
Web Services
Applications and Data
Energy Efficiency
Faster Interconnects
5 to 10 Years
Smart Appliances
and Standards
New home area networks
Secure Renewables
Two-Way Comms
OMS/DMS
Real-time Optimization
Integrated
Voltage Control
Value Based Services
Two-way Power Flow
Opportunities
Integrated Demand
Response
10-25 Years
True Two-way Power Flow
Transaction-less Renewables
Automated Home
and Businesses
Multiple Value Services
Anticipate outages,
Continuous
optimization, and pin
point accuracy of
system trouble and
restoration
Safe, Secure, Reliable and Resilient System
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NU: The Smart Grid Benefits All Stakeholders
The Smart Grid will create a digital energy system that
integrates new tools and technologies from generation,
transmission, and distribution all the way to consumer
appliances and equipment.
Self-Healing Wide-Area Protection
Distributed Generation & Alternate Energy Sources
Optimization and Improved System Efficiency
Asset Management and On-Line Equipment Monitoring
Source: Adapted from EPRI.
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Ambient (Clean Energy Coalition)Smart Grid Emerging Technology Roadmap
REGULATORY
INFORMATION
TECHNOLOGY
GRID DEVICES
TELECOM
Incremental
(0 – 3 Years)
Strategic
(3 – 10 Years)
Transformational
(10+ Years)
• Migration of 3G to LTE and rise of small
cellular
• Ongoing shift of wired to wireless
• Tighter integration of comm. and grid /
sensor technologies
• Telecom evolution will continue to
outpace utility adoption
• M2M growth
• Low bandwidth, high latency
• 3G cellular disappears
• Requirements for larger amounts of data
• Wired connections migrate to MPLS
networks/fiber pushed deeper into
networks
• Network data load continues to increase
• Devices utilize multiple paths/providers
rather than a single provider/path.
• Telecom / utilities back-office and
customer fulfillment integration
• Migration of 4G to 5G cellular
• Increased telecom capability evolves from
nice to have to required as utility,
healthcare, transportation become
dependent on data
• High band
• width, very low latency
• Centralized intelligence
• Initial development of the tools and
control schemes to manage the
distribution system
• Self-healing and IVVC focus
• DER “low” mkt penetration
• Central intelligence combined w/
local/distributed intelligence
• Ops driven by analytics & automation
• Shift to modularity and interoperability
• Adoption of telecom techniques for grid
management
• DER “medium” penetration
• Centralized intel combined with
widespread local/distributed intel
• Ops highly automated
• All devices have 2-way comm., memory,
and processing capabilities
• Hierarchical control of field devices
• DER “high” penetration
• Competing, proprietary standards
• Software is largely centralized and
siloed
• Architecture is centralized
• Message bus limited to data center
• “Big data” is big issue
•
•
•
•
•
• Applications and architecture fully
distributed
• Silo functionality largely gone
• Data mining and analytics becomes core
competency
• Approval contingent on annual review,
pilot
• Rate base business model
• Regulatory confusion about data,
disaggregation, privacy
• Benefits proven for “low hanging fruit.”
• Some regulation/mandates re: privacy, data,
operational functionality.
• Business model shifting from rate base to
services-focused.
Standards and interoperability focus
Software less centralized and siloed
Architecture shifting to distributed
Limited field message bus
New tools for mining data for intel
• Regulatory maturity
• Business model is full retail competition /
disaggregation
17
Unitil: Goals and Objectives
Reliable
Environmentally
Friendly
Efficient
Smart
Grid
Secure
Safe
Economic
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* U.S. National Energy Technology Laboratory
Unitil: Distribution Planning Approach
Evaluate
Options
Identify
Concerns
Option
B
System
Modeling
Option
A
Option
C
Cost
Recommendation
Benefit
Analysis
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NU: Project Selection Methodology
•
The process evaluates the customer service impact and considers
expenditure to create a cost benefit analysis

Other Considerations used in the Project Selection Process:
– Municipal or DPU Commitments
– Communities with historically lower reliability performance (low months between outage)
– Effect of outages on customers (Significant hardship versus minimal impact)
– Environmental and safety concerns
– Asset age and performance
– Service quality metrics
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Grid-Facing Subcommittee
Mtg. #2 Draft Agenda (2/26/13)
• Potential Grid Modernization Framework & Outcomes for Massachusetts
– David Malkin, GE presents on behalf of Subcommittee’s working group
• Potential Options & Strategies for Fast Two-Way Communication
• Potential Options & Strategies for Seamless Two-Way Energy Flow
• Potential Options & Strategies for Voltage/Var Control
– Kelly Warner, Applied Energy Group
• Subcommittee View Sharing and Discussion: Grid-Facing Modernization
– What are the most important grid-facing improvements needed?
– What is the appropriate pace for implementation of grid-facing grid
modernization?
– What are the most important criteria used to make grid-facing investment
choices?
– What regulatory policies should the group consider?
• Planning for Final Two Subcommittee Meetings
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