Transcript Distribution Volt/VAR Control

Irvine Smart Grid Demonstration
Bob Yinger | Southern California Edison
October 27, 2015
Objective
Demonstrate a cross section of what the
modernized grid might look like by 2020.
Demonstration Areas
•
•
•
•
Smart Energy Customer Solutions
Next-Generation Distribution System
Interoperability and Cybersecurity
Workforce of the Future
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.
Cost
• Project Cost
• DOE ARRA Funds
• SCE (in-kind)
• Partners
$79.2M
$39.6M
$26.9M
$12.7M
Key Dates
• Award
• Demo Start
• Demo Complete
12/09
7/1/13
6/30/15
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
Zero Net Energy Performance
Performance by ZNE Measure
Average Performance, by Method
Simulated
Performance Across Homes
TDV Method
0/9
0/9
3/9
5/9
5/9
Homes Achieving ZNE, by Method
TDV = Time Dependent Valuation
ZNE Home
Home Load
Without Energy Storage
•
•
•
•
•
With Energy Storage
EVSE Usage
ZNE Avg. Home Total Usage
Solar PV Generation
RESU Net Usage
ZNE Avg. Home Net Usage
Smart
Energy
Customer
Solutions
Worked well
Did not work well
Next steps
1. Energy storage can 1. HAN communications 1. Collaborate with DR
shift loads, level
for demand response
stakeholders to
demand, and provide
needs improvement
improve
backup power
communications and
2. Sub-optimized
interoperability for
2. 3 of 9 homes
energy storage hurts
key loads
achieved ZNE under
ZNE under TDV
the TDV method
2. Monitor and control a
3. Smart appliances
larger number of
3. Solar PV and LED
have limited DR
DERs to resolve grid
lighting had the
potential and low
challenges
largest impacts
customer value
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
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
Next Generation
Distribution
System
Worked well
1. DVVC can provide
energy savings of 1%
to 4% depending on
the type of circuit
Did not work well
1. The low-latency field
area network (FAN)
was unreliable
Next steps
1. Implement wide-scale
deployment of DVVC
2. Evaluate smart
2. Project battery
inverters and next
2. 2 MW battery operated
systems were early in
generation FAN
as intended to reduce
the development cycle
capabilities in
peak loading on a 12
(Required multiple
upcoming demos
kV distribution circuit
shutdowns for repair)
3. Continue to work with
3. Siting challenges –
energy storage
equipment and site
vendors to resolve
aesthetics is very
operational challenges
important
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
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
Interoperability and
Cybersecurity
Worked well
Did not work well
1. SA3 successfully
1. SCE needed to
demonstrated that an
assume system
HMI can be fully
integrator role
configured in minutes,
2. Needed more
instead of weeks
consistent vendor
2. SA3 Substation
adoption of IEC
Gateway proved the
61850
viability of automated:
3. Cybersecurity
• Substation
standards are still
configurations
emerging
• Change of
passwords
• Retrieval of relay
fault files
Next steps
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
Workforce of the Future
•Identified and developed the training
necessary to support the demonstration
of ISGD technologies
•Assessed potential organizational
implications of ISGD technologies
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
Workforce of
the Future
Worked well
1. A dedicated IT team embedded
at AT for cross-functional design
team collaboration
2. Workforce training – both inperson and on-demand
computer-based training, for
impacted personnel
3. Skills gap assessment approach
for future workforce needs
Next steps
1. Conducting workforce strategy
project as part of SCE’s grid
modernization effort
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
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
IGP Area
PRP Area
Bob Yinger
Consulting Engineer
Advanced Technology
Southern California Edison
[email protected]