Trends in Distribution Automation

Optimizing Distribution Network Operations
Ron Chebra– Principal, Utility Consulting Services

Leading Industry Trends
● Consolidation of software platforms
GIS, Planning, DMS, SCADA, OMS, EMS
● Convergence of IT & OT
Corporate IT and Operations IT silos
● Enterprise integration and Mobility
Sharing data throughout the enterprise and field
● Big data (from several new sources) and
Analytics
More intelligent devices, smart meters, data warehouse
● Operational asset management and
optimization
Leveraging new techniques for efficient use of assets
● Energy efficiency throughout the value chain
Network optimization, power control, demand response
● Managing distributed renewable energy (DER)
Increase in wind and solar with high intermittency
Today’sDiscussionFocus

SCADA
Alarming,
Tagging,
Trending,
Monitoring &
Control
OMS
Incident, fault,
customer call,
switching, and
crew mgmt and
reporting
DMS
Network
automation,
FLISR, VVO,
Energy Losses,
Relay Protection
EMS
Transmission &
Generation, AGC,
Economic
dispatch, Unit
commitment
DERMS
Distributed
Energy Resource
Management,
Load & power
forecasting
Geographic Information Systems, Common Infrastructure, Data Model, Security, History, User Interface
ADMS is a comprehensive network management solution with
monitoring, analysis, control, optimization, planning and training tools sharing
a common infrastructure, data model, and user experience
Platform Consolidation is happening
Platform Consolidation

Geographic Information System (GIS) is a “core” building block
● Initial layout and design
● Model Feeder topology by
phase
● CIM Adapter
● Graphic Work Design
integrated with WMS and
EAM
● Web, Desktop, Mobile
● Engineering Validation
● Supposed to eliminate
“Overbuild” to save costs

SCADA, Telemetry and Control
ADMS – Enhanced SCADA. New or traditional displays

Outage Management - OMS
ADMS – OMS, AMI and IVR Integration, Prediction

Platform Products
Service Infrastructure
Distribution Power Applications – Function Execution
ADMS – DMS functionality with list of power applications

Energy Management Systems
Automatic Gen Control
Scheduling
Scheduling
Visualization

Distributed Energy Resource Management (DERMS)
DERMS is a software-based solution that
increases an operator’s visibility in near real time
into its underlying distributed resource capabilities
distributed generation including renewables,
distributed storage, load actions and resource
management, demand response, etc.
Through such a system, distribution utilities have
heightened control and flexibility necessary to
more effectively manage the technical challenges
posed by an increasingly distributed grid assets
and their operating characteristics.

Microgrid Controller & Event Management
Reactive DER management
Ensures microgrid real time stability &
reliability
Manage of connect/disconnect from the grid
Optimize energy production & use
StruxureWare
Demand Side
Operation
Microgrid
Controller
Demand
response
requests
Energy market
pricing
Weather
forecast
Client
Constraints
Predictive DER management
Forecast when to produce, store or sell energy
Interface with energy markets
Accessible from anywhere
DER Box

Demand-Side Operations - DSO
1
2
3
DER Box
Customer
constraints
Weather
forecast
DR request
1
2
3
$
Market
prices

StruxureWare™ Demand Side Operation
• Cloud based platform for managing Microgrid Distributed Energy Resources
• SW DSO collects
• Microgrid energy data
• Weather forecasts (DTN)
• Market based energy pricing
• Manages DER to optimize:
• Demand-response programs
• Tariff-based incentives
• Self consumption
• Coordinates communication
with the smart grid
• Demand response requests
• Acknowledge, accept, reject
• Confirmation of action, payments, verification
Advanced algorithms help
making fast decisions about
cost-saving opportunities
Battery Charging and
Discharging Optimization
based on Demand Relief and
Economic Conditions

Realtime Bus
Advanced Distribution Management System
DMSSCADA OMS EMS
DERMSMWFM OAM
Feeder AutomationSubstation Automation
Enterprise Bus
ERP
Energy
Market
GIS
Network
Mgmt
AMI
Weather
MDM
Behind
theMeter
Common Platform
UI Model SecurityHistoryData
Utility IT/OT Solution
DER/Microgrid Automation
IT/OT Convergence

Utilities are adopting solutions that leverage the
connectedness of “things” (IoT, or Grid of Things GoT)
14
Smart Field Controllers
Advanced Distribution Management Systems
PQ
meters
Remote Terminal Units
Faulted Circuit Indicators
Relclosers
Making greater use of intelligent end devices
(IED)
Leveraging more and greater field intelligence
Deploying communication networks that link
devices to devices and to control systems
Integrating self-healing distribution networks
Providing layers of information interchange at the
control room and in the field
Intelligence, Communication and Control are essential
elements of the solution to provide the service required
IT/OT Convergence

An Example of Grid of Things
Challenges
Focus Areas
Integrated
Solutions
Devices and Tools
15Source: Schneider Electric
IT/OT Convergence

Voltage Profile – Power at substation diminishes over distance
Lower Regulatory
Limit
114v
Upper Regulatory
Limit
126v
VVO and Capacitors flatten profile allowing voltage reduction
Existing
Flattened Profile after VVO
Lower Voltage to Reduce MWs
CVR/VR
FeederVoltage
Feeder Length
Voltage and VAR Control
ADMS+Capacitors and LTC
Efficiency
leveraging the
value chain

Recloser 3
Recloser 4
2D
Feeder Recloser 2
2B
2A
1A
Recloser 2
1D
1B
Feeder Recloser 1
2C
1C
B
Recloser executes a trip and goes to lockout.
Feeder Recloser Trips and Locks Open
Closed
Tripped
Switchgear
Live
Dead
Line
Modbus Trip Request
Roles Change, Protection Groups and “Direction of flow”
Tie Recloser
Modbus Close Request
Recloser 1
B+SS
BB+SS
Substation 1
Appropriate Reclosing Tie Point is
Closed. Now a Recloser in scheme
Loop Automation Activation Delay
timers start due to a loss of supply.
> Fault isolated, with capacity check
> Power restored to unfaulted sections in less than 1 minute
> No operator intervention Safety: No re-energizing into fault
Distribution Automation - Switching and Reclosing
Substation 2
Recloser
Efficiency
leveraging the
value chain

Confidential Property of Schneider Electric
Efficiency
leveraging the
value chain

From a Utility Perspective, Distributed Resources
may be any one of these, regardless of size and scale
• Non Renewable Predictable and Controllable Distributed Generation Resources (DG) - Microturbines, CHP, Fuel
Cells, etc. that have know ramp times, capacity and availability
– Key Characteristic – They can be located remotely and placed near loads
• Wild Distributed Energy Resources Renewable (wDERr)– Solar or Wind Farms that leverage natural resources to
generate energy
– Key Characteristic – Intermittent and Variable due to natural conditions
• Tamed Distributed Energy Resources Renewable (tDERr)– Solar or Wind Farms that are augmented with energy
storage to mitigate intermittency
– Key Characteristic – Smoothing may be limited to storage type, AH capacity, and cycling
• Microgrids (MG)- “A group of interconnected loads and distributed energy resources (DER) with clearly defined
electrical boundaries that acts as a single controllable entity with respect to the grid [and can] connect and disconnect
from the grid to enable it to operate in both grid-connected or island mode.” - Department of Energy
– Key Characteristic – Operate in either grid connected or islanded mode depending on conditions or situations
Distributed Resources

Minutes Seconds
Asset run time and fuel source make these assets very useful for many applications;
however ramp time and other factors, such as EPA restrictions many limit their use

Wild Distributed Energy Resources- Renewables

Wild DER + Storage = Tamed DER

Source: Adapted
from EPRI
Institutional campus
e.g. university,
hospitals
>20 MW
~5 to 15 MW
~2 to 5 MW
~ 10K to 2 MW
Communities tied to the larger utility
grid
Microgrids

What are some of the components of a typical MicroGrid?
24
Gen
Set
Micro-
Turbine
Battery Storage
Wind Turbine
PV Panel Arrays
DC/AC
Inverters
DC/AC
Inverters
Battery
Charging
Systems
Controller
Controller
Micro Grid
Controller
Intelligent Switch
Power
Status
Command
Control
PCC
Point of
Common
Coupling
Schneider
Electric
Components

DER and Microgrid: Utility Adoption Rationale and Applicability
Rationale DG
($-$$$)
Wild DER-
R ($)
Tamed
DER ($$)
M Grid
($$$)
1. Alternative to new centralized peak generation plant
2. Alternative to new sub-transmission lines or stations
3. Alternative to new Distribution Substations
4. Distribution Grid Resiliency
5. Distribution Grid Stability
6. Meeting Renewables Mix Objectives
7. Support Economic Development
8. PUC Regulatory Political Anticipation
9. Customer Retention – Avoid Defection
10. New Business Expansion for Utility
SCALE Most
Applicable
Likely
Applicable
Partially
Applicable
Least
Applicable

Utility DER as….
1) Alternative to new centralized peak generation plant
> Drivers
– Green Alternative to boost your mix of
clean energy
– Fuel Diversity
– Locate power close to loads
– Multiple small scale source vs. one large
source
– Supply can be aligned with load
requirements and scale
– Does not involve additional
(sub)transmission connections
– Connects to MV Distribution System
– Alternative to Centralized VVO/CVR-type
Optimization
> Examples
> LIPA/PSE&G power service for peak relief
at end of Long Island
> California AB-2514 PUC energy storage
mandate to manage the “duck curve”
demand ramp
> Key Requirements:
> Dispatch controllable, predictable, AGC
> Anywhere where peak service or relief of
asset overloading is required

Utility DER as….
2) Alternative to new sub-transmission lines or stations
> Drivers
– Green Alternative
– Supply a seasonal or transient peak for a
targeted area
– Supply a area of demand growth
– May be much more economical than building
new Transmission lines/stations/connections
– Fewer permits and ROWs
– Anywhere where peak service or relief of asset
overloading is required
– DR+ instead of DR- = greater control
• Examples
– LIPA/PSE&G power service for peak
relief at end of Long Island
• Key Requirements
– Base and Peak Demand
– Peak Energy Need
– Localized and Distributed
– Voltage and Frequency Support

Utility DER or Microgrid as….
3) Alternative to new Distribution Substations
> Drivers
– Green Alternative
– Right size supply needs where needed on
distribution system
– Does not require transmission tap
– Installs where needed, on distribution system
near loads
– Easier to install and operate
– Reduce overloading during peaks
– Connects to MV Distribution System
– Alternative to Centralized VVO/CVR-type
Optimization
– DR+ instead of DR- = greater control and
revenue
• Examples
– ConEdison BQM Load Relief
– Base and Peak Demand
– Localized and Distributed
– Voltage and Frequency Support
– Controllable and Reliable
– Supply and Island

Utility Microgrid as….
4) Distribution Grid Resiliency
> Drivers
– High availability resource to recover
– Community/Emergency Services
• Fire, Police, Pharm, Food, Fuel,
Communications
– Utility supports important to
constituents/municipalities
– Grid Hardening
– Black Start Support of
Distribution System
– Ability to supply Islands within the
distribution system
• Examples
– Department of Energy and
Environmental Protection (DEEP)
– Connecticut Microgrid Funding
– NY Prize Program
– Island and Black Start

Volt/VAR Response
Source: SWIG Report 1/2014
5) Distribution Grid Stability
> Drivers
– Distribution Frequency Support
– Distribution Voltage Support
– Distribution VAR Support
– Alternative to Capacitors and
Voltage Regulation (which require work now)
– Storage + DER can smooth variable
supply of renewable sources
– Can supply Islands in the distribution
system during a macro disruption
• Examples
– Commonwealth Edison – Shedd
Aquarium
– Puerto Rico
– VAR Injection
– Voltage Support
– Fast Frequency Support
Frequency Ride Through
Source: SWIG Report 1/2014
Voltage Ride Through

6) Meeting Renewables Mix Objectives
> Drivers
– Political and Regulatory bodies will drive
States which will drive Utilities to reduce
traditional carbon-based resources and
increase renewables
• EPA, State, PUC, City Council….
– EPA Clean Power Plan
• Sweeping reductions by 2030
– RPS Renewable Portfolio Standard
• Typically 20-30% for variable renewables
– Progressive image for Utility or offer new
programs (community solar)
• Examples
– Southern California Edison –
Preferred Resources Program
(100MW)
– Massachusetts DOER Renewable
Energy Portfolio programs
– Regulatory
– Support Planet-Climate Change
– Holistic optimization and control of
DERs

7) Support Economic Development
> Drivers
– Basis for Smart Cities
– Socially Responsible Development
– Support the Prosumer
– Leverage additional funding channels
• Developer Investment
• Municipal Investment
• Private Equity funding of CHP/MG/DER
– Provide right amount of power now, with
scalable future
– Green and Progressive Image for Coop,
Muni or IOU
– Make your system attractive to new or
expanding industry
• Examples
– Hoboken NJ,
– Philadelphia Navy Yard,
– Brooklyn Army Terminal,
– BGE support of municipals, others
– Meet system growth demands
– Meet Sustainability
– Utility able to absorb operation into
their business process (DERMS)
– Good management tools and
processes

8) PUC Regulatory Political Anticipation
> Drivers
– Pilot or Demonstration Program conducted
ahead of regulatory mandates or drivers
– Gain Experience and Lessons
– Prove operational concept with utility control
center, load operators and field operations
– Validate Infrastructure required to support
• Technology
• Personnel
• Operational Processes
• Examples
– NY REV
– Oncor (MicroGrid Demo Center)
– Duke (COWI and II)
– CPS Energy (VIP)
– Prove Storage application on
distribution system
– Integration with existing systems
– Use of new communications
Architectures
– Ability to test and simulate

9) Customer Retention – Avoid Defection
> Drivers
– Customers are going to choose MG/DER
alternatives for themselves
– Provide more reliable, resilient power
– Add new revenue stream, within regulatory
constraints
– Make it happen vs. What happened?
– Utility in Control of technologies
– Optimize Rate Structures (TOU vs. Flat Rate)
– Avoid loss of revenue from customers going “off
grid” as well as “out of grid”
• Examples
– Shedd Aquarium
– Walmart
– Supply close to load
– Co-Ownership
– New PPAs
– New SLAs
– New Partners

10) New Business Expansion for Utility
> Drivers
– Un-Regulated side of IOU. Marketplace not
constrained to regulated business areas
– Community Microgrid/DER at Muni or Coop
– Utility has skills and tools to manage this better
than 3rd party
– Consumers “trust” utility to manage power
systems
• Examples
– Duke Engineering Services (non-reg
side)
– Expansion of previous “Back Up
Gen” services into Microgrids
• Key requirements
– Utility willingness to pursue new
business areas
– Regulation supports these
“expansions” of the distribution
system

Now that utilities increasingly using Distributed Energy
Resources, as “grid assets”, the use of “traditional” DA
techniques must now be modified to include these elements and
their capabilities to optimize the performance and fault
management of feeders.
Recloser
Reclosers
Feeder Recloser
1
Tie Recloser
Recloser
Feeder Recloser
Recloser
Cap Bank
Cap Bank
Voltage Reg
Voltage Reg
Cap Bank
Substation
Transformer,
Capacitor Bank,
Voltage Regulator
MicroGrid
Wild DER
Advanced
DMS/PCS
Storage

 A given feeder (e.g. 101) serves residential and commercial customers, who have
Advanced Metering Infrastructure (AMI)
 There is a community area that is operating as a MicroGrid,
 The utility has customers subscribed to a demand response program that can
provide emergency load reduction
 The feeder is configured in a “loop” with a Tie switch that can connect an alternate
feeder (e.g. 212) for supply
 This feeder is equipped with remotely controllable cap banks, midpoint switches and
reclosers
 The utility has an Advanced Distribution Management System (ADMS) and all
devices are connected to a network
Situation:
Example: Feeder with a community that is a MicroGrid
How can information, access and centralized operation along with a neighborhood microgrid,
improve the operation of Fault Location, Isolation and Supply Restoration (FLISR) on a
distribution feeder?

Our Feeder is configured in a loop with alternate supply. It also has a
Community based Microgrid along with Demand Response Subscribers.
R S S
T
R S S
Feeder 212
Feeder 101 “A” “B”
“C”
“X” “Y”
“Z”
16 MW 6 MW
8 MW
5 MW Need
4 MW produced
locally
S
10 MW18 MW 6 MW
Closed
Open
R – Recloser
S – Switch
T – Tie Connection
ADMS
DERMS/
DSO
Normal Conditions
30 MW
34 MW

Assume a Permanent Fault occurs in section “A”
R S S
T
R S S
“A” “B”
“C”
“X” “Y”
“Z”
16 MW 6 MW
8 MW
5 MW Need
4 MW produced
locally
S
10 MW18 MW 6 MW
Closed
Open
R – Recloser
S – Switch
ADMS
DERMS/
DSO
FAULT
Feeder 212
Feeder 101
30 MW
34 MW

Recloser locks out after multiple attempts – sections A B and C are without
power, AMI last gasp verifies outage in impacted areas; Microgrid is isolated; all
status is communicated to Headend
R S S
T
R S S
“A” “B”
“C”
“X” “Y”
“Z”
16 MW 6 MW
8 MW
5 MW Need
4 MW produced
locally
S
10 MW18 MW 6 MW
Closed
Open
R – Recloser
S – Switch
ADMS
DERMS/
DSO
Fault Conditions
Feeder 212
Feeder 101
0 MW
34 MW

The Community, under DSO control, reduces non critical loads to balance
supply and demand; Fault is isolated to section A, capacity is checked at feeder
212
R S S
T
R S S
“A” “B”
“C”
“X” “Y”
“Z”
16 MW 6 MW
8 MW
5 MW Load
4 MW produced
locally
S
Closed
Open
R – Recloser
S – Switch
ADMS
DERMS/
DSO
Fault Conditions
Feeder 212
Feeder 101
0 MW
10 MW18 MW 6 MW
34 MW
4 MW Load

R S S
T
R S S
“A” “B”
“C”
“X” “Y”
“Z”
16 MW 6 MW
8 MW
4 MW Load
4 MW produced
locally
S
Closed
Open
R – Recloser
S – Switch
ADMS
DERMS/
DSO
Fault Conditions
However, feeder 212 needs to reduce its load by 3 MW in order to also serve the load
on B and C, so the ADMS does a DR call to reduce loads on X; Y and Z
Feeder 212
Feeder 101
0 MW
10 MW
18 MW
6 MW
34 MW

R S S
T
R S S
“A” “B”
“C”
“X” “Y”
“Z”
16 MW 6 MW
8 MW
4 MW Load
4 MW produced
locally
S
Closed
Open
R – Recloser
S – Switch
ADMS
DERMS/
DSO
Fault Conditions
ADMS Verifies load reduction on Feeder 212 through AMI and sensing at the switches;
protection settings on Tie and switches and the recloser on Feeder 212 are changed
Feeder 212
Feeder 101
0 MW
9 MW17 MW 5 MW
31 MW

S
T
R S S
T
R S S
“A” “B”
“C”
“X” “Y”
“Z”
16 MW 6 MW
8 MW
4 MW Need
4 MW produced
locally
S
9 MW17 MW 5 MW
Closed
Open
R – Recloser
S – Switch
ADMS
DERMS/
DSO
Feeder 212
Feeder 101
0 MW
45 MW
ADMS Closes Tie Switch and energizes healthy section B and C; Community remains
Islanded; restoration of section B and C is verified through AMI messages
Partial Restoration

Fault is cleared - Tie opened, Feeder 101 Recloser and switch restored, all DR events
are cancelled, Protection schemes restored, Restoration verified by AMI, DSO Restores
Normal Conditions with MicroGrid
R S
S
T
R S S
T
R S S
“A” “B”
“C”
“X” “Y”
“Z”
16 MW 6 MW
8 MW
5 MW Need
4 MW produced
locally
S
10 MW18 MW 6 MW
Closed
Open
R – Recloser
S – Switch
ADMS
DERMS/
DSO
Normal Conditions
Feeder 212
Feeder 101
30 MW
34 MW

Summary of events
Recloser quickly isolates faults; Community is islanded
AMI verifies fault location via “last gasp” and by switch
information
ADMS verifies capacity to switch load, since more supply is
needed, a DR call is made to Feeder 212
AMI verifies load reduction on Feeder 212
Tie switch is energized to supply un-effected segments
Fault is more quickly fixed
Normal service is restored
AMI meters are “pinged’ to verify no nested outages exist
after restoration
Fewer customers
impacted by a fault, the
community remains light
through islanding and
reconfiguration happens
in minutes
Circuit is protected from
back feed
Since the fault is isolated to
smaller area, restoration
happens faster
Crews do not have to be re-
dispatched to field

Questions?
Page 47
Confidential Property of Schneider
Electric |

Thank You
Page 48
Confidential Property of Schneider
Electric |
Ron Chebra
Ron.Chebra@Schneider-Electric.com
+1 609-865-0166

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