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

Toda

y’s

Dis

cuss

ion

Focu

s

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

Platform Consolidation

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) Platform Consolidation

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

DMS SCADA OMS EMS

DERMS MWFM OAM

Feeder Automation Substation Automation

Enterprise Bus

ERP

Ener

gy

Mar

ket

GIS

Net

wor

k M

gmt

AMI

Wea

ther

MD

M

Behi

nd

th

e M

eter

Common Platform

UI Model Security History Data

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 15 Source: 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

Feed

er V

olta

ge

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

B B+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


Confidential Property of Schneider Electric


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 Distributed Resources

Wild DER + Storage = Tamed DER Distributed Resources

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 Distributed Resources

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

• Key Requirements

– 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

• Key Requirements – 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 MW 18 MW 6 MW

Closed Open

R – Recloser S – Switch T – Tie Connection

ADMS DERMS/

DSO

Normal Conditions

30 MW

34 MW

http://www.google.com/url?sa=i&rct=j&q=&esrc=s&source=images&cd=&cad=rja&uact=8&docid=cfXP9CbxvCAl0M&tbnid=6b3MPrV_iXUYiM:&ved=0CAcQjRw&url=http://www.smartmetereducationnetwork.com/how-to-tell-if-I-have-a-ami-dte-smart-advanced-meter.php&ei=nlIgVO65JJaqyATHz4CgAg&bvm=bv.75775273,d.aWw&psig=AFQjCNGShu7GtIE6ETBfiJJnOy_n5dlf-Q&ust=1411490840063649


















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


S

10 MW 18 MW 6 MW

Closed Open


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


S

10 MW 18 MW 6 MW

Closed Open


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


ADMS DERMS/

DSO

Fault Conditions

Feeder 212

Feeder 101 0 MW

10 MW 18 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


S

Closed Open


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


S

Closed Open


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 MW 17 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


S

9 MW 17 MW 5 MW

Closed Open


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


S

10 MW 18 MW 6 MW

Closed Open


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 [email protected] +1 609-865-0166

mailto:[email protected]

