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MESA-ESS Technical
Work Group Webinar
April 15, 2015
Agenda
• Organizational Overview
• Coordination and Collaboration with Other
Distributed Energy Resources (DER) Communication
Efforts
• MESA-ESS Technical Working Group
• Getting Involved
• Q&A
2
MESA Members
3
MESA Standards – Importance of Standards-Based Control
Systems
• Standards-based
communications lowers
integration costs
• Minimal NRE encourages rapid
propagation in a service area
• Modularity allows for
component replacement as
technology advances
• Compatible products can be
extensively tested prior to
installation
• Easier to support and
maintain in
the field
4
Coordination and Collaboration with
Other Distributed Energy Resources
(DER) Communication Efforts
April 15, 2015
Xanthus
Consulting International
Frances Cleveland
[email protected]
Topics
• Ongoing California Efforts impacting the development of
MESA Standards
• Existing Communication Standards
– IEC 61850 for DER
– IEEE 1815 DNP3
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Impact (Positive and Negative) of DER on Distribution
Operations
•
•
•
•
•
Renewable energy portfolios (RPS), as well as customer interests in reducing
energy costs, are incentivizing additional renewable energy, often at the
distribution level
DER systems in low penetrations are just negative load
However, DER systems at higher penetrations can impact distribution
operations both negatively and positively
“Smart” DER technologies and grid modernization equipment are changing the
nature of distribution planning and operations
In particular, energy storage, when flexible in capabilities and coordinated with
generation resources, can significantly benefit power system operations
“In the near future, utilities may no longer just supply electricity to
customers, but may have to plan for, coordinate, and manage the
flow of energy to, from, and between customers.”
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Ongoing California Efforts Impacting the
Development of MESA Standards
• California Energy Storage Goals, October 16, 2014 (D. 1410-045)
- Mandates 1,325 MW of energy storage procurement
for California IOUs
• Development of California IOUs’ Distribution Resource
Plans (DRP)
- DRPs will take into account DERs and particularly energy
storage as part of future planning
- Communications for operation of these planned storage
installations will be critical
• Smart Inverter Working Group (SIWG)
- Developing the default DER functionality requirements
and establish an implementation plan for California
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Evolution of DRP Optimal Location Benefits Analysis
• What are the immediate benefit categories that can reasonably be evaluated
within the next 3 months for the first DRP (July 1, 2015)?
• What are the next logical set (incl. data and tools needed) for system-wide
DRPs?
No. of Benefit Categories &
Sophistication of Analysis
• Vital to establish the communications to DER and ESS to allow evaluations.
Run
Jog
Walk
2015-1H 2016
System-wide DRPs incl.
Locational Societal Benefits
System-wide DRP including LTPP
& TPP locational benefits
Visibility & Initial DPA Locational Benefits
2H 2016-2019
2020+
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California’s Smart Inverter Working Group (SIWG)
• California (CEC and CPUC) did not want to repeat the European scenario
and initiated the Smart Inverter Working Group (SIWG)
• The SIWG was convened in January 2013 to:
– Develop the default DER functionality requirements and establish an
implementation plan for California
– Update California’s Rule 21 on DER interconnection requirements
• The SIWG currently has over 250 participants from all major stakeholder
groups, including utilities, DER manufacturers, integrators, customer
groups, investors, and interested parties
– After being hesitant during the first month of weekly calls, all stakeholders
recognized the potential benefits of “smart inverters” and eagerly joined in
the technical discussions
– California’s three IOUs have taken the lead in defining their requirements,
while the DER manufacturers have determined what their products and
technologies can achieve
– Typical discussions are: “Should the timing be .2 or .3 seconds?”
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SIWG Results to Date and Implications for MESA’s Efforts
• The SIWG developed a phased approach of
recommendations to the CPUC:
– Phase 1: Seven (7) critical autonomous functions – approved by CPUC
in December 2014 and mandatory by mid 2016
– Phase 2: Communications capabilities for monitoring, updating
settings, and control – submitted to the CPUC in late February, 2015
– Phase 3: Additional DER functions – currently being discussed – open
to all who want to address these technical DER capabilities
• Opportunity for MESA to collaborate and coordinate on this work
• SIWG members now participating in a survey on the
importance of about 40+ DER functions and use
cases
11
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Intersection of SIWG Phase 2 and MESA Efforts
Communications between utilities and other entities (red
lightening bolts):
• (1) Utilities and individual DER Systems – MESA focus
• (2) Utilities and Facility DER Energy Management Systems
• (3) Utilities and Aggregators
13
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SIWG Efforts Spawned Updates to Standards
This California SIWG process and other initiatives have
triggered related efforts to update standards:
– UL 1741, required for safety of DER installations, is developing a
supplement to provide testing and certification for these
functions, and is almost ready for ballot.
– IEEE 1547, which is used by most jurisdictions as the standard for
DER interconnection requirements, was amended as IEEE 1547a
to permit these functions. IEEE 1547 is now being completely
revised to cover these and a number of other functions.
– IEC 61850 Information Model is being updated to include new
objects for new DER functions.
– IEEE 2030.5 (Smart Energy Profile 2) communication protocol is
being expanded.
– IEEE 1815 (DNP3) SCADA protocol is adding Profiles for DER.
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IEC 61850 as UML-based Abstract Information Model
• IEC 61850 is now modelled in UML (Unified Modeling Language)
• UML model allows extractions of different formats, such as MMS
(current standard) or XML/XER XSDs (Internet standard)
• IEC 61850 UML model provides a single standard source of data
objects, thus minimizing the risk of inconsistencies in implementations
• Data objects can be used over different service and transport protocols,
including XMPP (planned 61850-8-2 standard)
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IEC 61850-7-420 and 61850-90-7 Volt-Var Curves: Basic Curve and with Hysteresis
VARs Generated
Example settings for
providing % of available vars
P1 (V = 97 %VRef, Q = 50 % VArAval)
Capacitive/
Overexcited
Voltage-Rising/Falling
P3 (V = 101 % VRef, Q = 0 % VArAval)
System Voltage
P2 (V = 99 %VRef, Q = 0 % VArAval)
Inductive/
Underexcited
P4 (V = 103 % VRef, Q = –50 % VArAval)
IEC 61850 modeling structures:
Logical Devices (LD)
Logical
Nodes
(LN)
Logical
Nodes
Data Objects (DO)
Common
Data Data
Classes
(CDC)
Common
Class
–
–
–
–
–
V = voltage
VRef = reference voltage
VArAval = available vars
WMax = maximum watts
PF = power factor
Example Settings with
Use of Hysteresis
VARs Generated
•
• IEC 61850 provides wellknown names and
structures of data objects:
P4 (97 %VRef,
Q = 50%WMax)
P1 (99%VRef,
Q = 50%WMax)
Voltage-Rising
Voltage-Falling
Overexcited
System Voltage
Underexcited
P2 (103%VRef,
Q = -50%WMax)
Common
Attributes
Common
Components
Standard Data Types
P3 (101%VRef,
Q = -50%WMax)
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IEC 61850-90-10: Scheduling
• Schedules:
– Time-based schedules for activating a function or initiating specific modes
•
•
•
•
•
From 6:00 am to 12:00 pm, turn on and use mode 3
From 12:00 pm to 5:30 pm, use mode 5
From 5:30 pm to 7:15 pm, use mode 8
At 7:15 pm, turn off
Repeat schedule every weekday during the summer
– Schedules have priorities and can be overridden by emergencies or other
commands
Validated
Legend:
Not Ready
Not Ready
Validated
Ready
Running
active
Prio 2
Prio 1
Prio 1
Prio 0, Periodic
t1
Prio 1
Prio 0, Periodic
t2
t3
Prio 0, Periodic
t4
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t5
Prio 0, Periodic
t6
t7
time
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MESA-ESS Technical Working Group
19
MESA Interface Summary
Utility SCADA/EMS/DMS
DNP3
MESA-ESS
Software
Energy Storage Control System
ESS
MESA-Battery
MESA-PCS
Battery
Management
System
Programmable
Logic
Controller
Battery
PCS
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Modbus
Grid
MESA-ESS Strawman
• Technical Working Group will start with a
strawman developed by MESA Members
• Strawman
– Standardized DNP3 profile for communicating with
energy storage systems
– Profile is based on AN2013-001: DNP3 Advanced
Photovoltaic Profile
– Designed to support multiple ESS configurations
• First implementation currently being field tested
as part of Snohomish PUD’s MESA-1a project
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MESA-ESS Technical Summary
• Provides monitoring and control points for the
system as well as individual power conversion
systems, batteries, and meters
• Enables the configuration and execution of
multiple operating modes
• Scheduling functionality allows the ESS’ behavior
to be controlled over an extended period of time
• Local/Remote/Automatic control management
helps to ensure safe operation
• Constrained to DNP3 Level 2 to ensure broad
support
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Monitoring and Control
System Level
Local/Remote/Automatic Control
Alarm Summaries
Start System
Emergency Shutdown
Etc.
Device Level
PCS Real Power Output
PCS Reactive Power Output
Battery State of Charge
Battery DC Bus Voltage
Meter Real Energy Delivered
Meter Frequency
Etc.
Multiple Configurations
1 PCS + 1 Battery  50 PCSs + 50 Batteries
Multiple meter types, locations and configurations
One or two PCSs per transformer
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Operating Modes
• MESA-ESS enables the
configuration and execution of
multiple operating modes
• Allows operating modes to be
combined for more complex
operation
Supported Operating Modes
Limited Watts
Charge / Discharge
Fixed Power Factor
Power Factor Correction
– e.g. Real Power Smoothing +
Power Factor Correction
Dynamic Volt-Watt
Peak Power Limiting
• Modes and parameters are
consistent with DNP3 AN2013001 and EPRI Common
Functions for Smart Inverters
wherever possible
Real Power Smoothing
Load and Generation Following
Spinning Reserves
AGC
24
Scheduling
• Supports the creation of up to 50 schedules with 100
time-based setpoints each
• Configurable granularity
– 15-minute granularity = 25 hour max duration
– 1-hour granularity = 4 day max duration
• Schedules can be configured to control real power
output, power factor correction, etc.
– More schedule types planned for the future
• Rich repeating options
– e.g. Run this schedule every M, T, W and Th
• Schedules may be combined for more interesting
scenarios
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MESA–ESS TWG Tasks
• Determine which DER functions could be provided by Energy
Storage Systems (ESS)
• Determine what data is needed between utilities and ESS units.
– Potential to extend to FDEMS or Aggregators that manage ESS units
• Continue to review existing standards: IEC 61850, DNP3 mappings,
SEP2, etc. to determine what already exists, what more is needed,
and if any existing objects need to be modified
• Develop communication specifications for MESA-ESS,
– Using existing data objects
– Developing new data objects based on IEC 61850 and DNP3 mappings
– Determine performance requirements, including availability, latency,
aggregation, statistical requirements, cyber security, privacy, etc.
• Review possibility of additional specifications for other protocols
• Submit the communication specifications to the appropriate
Standards Development Organization (SDO)
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MESA-ESS Timeline
What
Recruit new MESA-ESS workgroup
members
Begin workgroup meetings
Develop initial standard; solicit
feedback and make appropriate
adjustments to the specification
Publish draft specification for broad
public review
27
When
Now
April 2015
April-Fall 2015
End of 2015
MESA Membership Structure
Contributing Members
Supporting Members
•
•
Nonprofit or government
organizations
•
Can participate in general meetings,
have access to the Members-only
website and discussion forums
•
May be nominated and elected to the
Board of Directors after September
2015
Industry equipment manufacturers,
software suppliers, and utilities
(public and private)
•
Can vote and participate in work
groups and committees
•
May be nominated and elected to
the Board of Directors after
September 2015
Cost:
Revenue USD >100M
• $5,000 per year
Revenue USD 1M – 100M
• $3,000 per year
Revenue USD <1M
• $1,500 per year
Cost: $1,000
28
Questions?
Membership:
Darcy Wheeles: [email protected]
Margot Malarkey: [email protected]
Technical:
Frances Cleveland: [email protected]
Andrew Miller: [email protected]
For more information and to sign up for updates go to
www.mesastandards.org
APPENDIX SLIDES
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A Little History – Renewables and DER in Europe
• Europe pushed for renewables for 20 years,
mostly hydro and wind at the transmission
level
– Achieving > 60% in some countries
– But far less in others
– Goal is combined Europe of 20% by 2020
•
•
Distributed Energy Resources (DER) still make
up only a small percentage (3 – 6%)
However, European experiences, including a
2003 blackout in Italy, have shown that DER
systems must support the grid for both
reliability and economic reasons:
– Specifically, DER systems need at least to be able to “ride-through” both
frequency and voltage short-term anomalies
– Europeans had to retrofit large numbers of DER systems to add these
critical capabilities – a very expensive action
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A Little History – Renewables and DER in California
•
As part of achieving 33% renewables by
2020, California Governor Jerry Brown called
for 12,000 MW of DER
•
Now the goal has been updated to 50%
renewables by 2030, with a probable
increase in MW from DER
•
Most of the renewable energy comes from
transmission-connected wind and solar plants
•
DER systems are defined as distributionconnected generation, energy storage, and
•
(sometimes) controllable load
•
High penetrations of DER systems have the
•
potential to provide significant
environmental and financial benefits to
Californian transmission, distribution, and
customers
•
Utilities benefit not only from energy but
also ancillary services
32
However, DER systems also present major
challenges to managing the grid
Smart Inverter-based DER, particularly
energy storage, are capable of providing
these benefits while helping to mitigate
the adverse impacts of intermittency,
voltage sags / spikes, and frequency
anomalies
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California’s Energy Storage Goals
CPUC Decision 14-10-045 October 16, 2014
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Phase 1: Seven Autonomous DER Functions
• SIWG Recommendations for Phase 1 Functions – These
Affect Storage as Well as Generation:
– Support anti-islanding to trip off under extended anomalous
conditions, coordinated with the following functions
– Provide ride-through of low/high voltage excursions beyond normal
limits
– Provide ride-through of low/high frequency excursions beyond
normal limits
– Provide volt/var control through dynamic reactive power injection
through autonomous responses to local voltage measurements
– Define default and emergency ramp rates as well as high and low
limits
– Provide reactive power by a fixed power factor
– Reconnect by “soft-start” methods (e.g. ramping and/or random
time within a window)
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SIWG Phase 2 Communications: DER Management Challenge:
Large Numbers of Disparate DER Stakeholders with Different Purposes and Different Financial
Interests
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DER Configurations, SEP2, and Other Protocols
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SIWG Phase 3 DER Functions: Opportunity for MESA
Influence
•
•
Discussions on relative importance of 40+ DER functions, to which stakeholders,
which might need further technical resolutions, and which should be included in
Rule 21.
Some of Phase 3 functions include:
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–
–
–
–
–
–
–
–
–
–
–
–
Provide status, measurements, and forecast real power output/charging
Set actual real power output
Limit maximum real power output
Frequency-watt: Counteract high/low by changing watt output
Voltage-watt: Counteract voltage variations by changing watt output
Watt-power factor: Change power factor based on watt output
Provide fast VAR Support for voltage mitigation
Frequency smoothing: Smooth frequency variations by changing watt output
Automatic Generation Control (AGC): Participate in AGC
Schedule actual or maximum real power output, charging, or modes
Provide black start capability
Provide operational reserves
Provide backup power
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California’s Distribution Resource Planning (DRP)
• Purpose is for distribution planning to include DER energy capacity, “smart”
capabilities, energy efficiency, and market incentives during long-term
distribution planning
• These factors would then be added to the avoided costs of “traditional”
distribution planning, minus DER integration costs
• Process is to define a list of mutually exclusive and collectively exhaustive
(MECE) categories of values
Perform Planning
Analyses
Calculate Locational
Net Value
$16
$14
$12
$10
$8
$6
$4
$2
$-
Locational Value: Avoided
Costs and Benefits
Rank Substations by
Locational Net Value
$16
$14
$12
Net Locational Value
by Substation
$10
$8
Millions
Identify DPA &
Substations
$6
$4
Locational Integration
Net
Value
Cost
Locational
Value
$2
$-
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