Distribution Feeder Automation - MASC Associations/06-18... · Distribution Applications Guide...

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Joshua W. Timm, PE

Distribution Feeder Automation:

Introduction – What, When, & Why’s of DA

© Booth & Associates, LLC. 1

Introduction: What, When & Why’s of DA

Outline

Define DA – “What”

System planning - “When”

Key benefits – “Why”

2© Booth & Associates,LLC.

3© Booth & Associates, LLC

DA: Introduction The “Grid” The “Feeder”

Source: North American Electric Reliability Corporationhttp://www.nerc.com/AboutNERC/Documents/Understanding%20the%20Grid%20DEC12.pdf

The information provided here is for informational and educational purposes and current as of the date of publication. The information is not a substitute for legal advice and does not necessarily reflect the opinion or policy position of the Municipal Association of South Carolina. Consult your attorney for advice concerning specific situations.

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Basic Initiatives Reliability Power Quality Safety Distribution Efficiency Affordability

Customer Satisfaction!


DA: Introduction Traditional “Grid”

Relatively passive

Voltage Regulation

Simple Control set-points

Fixed schedules

Local sensors / Limited visibility

Electro-mechanical devices

“Static” intelligence

Engineering Analysis

Predictable Loads

System Protection

Fuses, Breakers, Relays

Outage Location

Customer Calls


DA: Introduction Modern “Grid”

Greater demands

Resiliency

Power Quality

Customer Participation

Solar / Wind

Energy storage systems

Outage Communication

Advances in Distribution Automation Technology areleading the way…

Today’s Initiatives Reliability / Resiliency Power Quality Safety Distribution Efficiency Affordability Customer Participation Customer Communication



DA: Introduction

Source: Department of Energy, QTR 2015https://energy.gov/sites/prod/files/2017/03/f34/qtr-2015-chapter3.pdf

The modern distribution system:

145 million customers

6.3 million miles of line

Often expensive & difficultto upgrade

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Distribution Automation:

Smart Grid

Smart Distribution

Distribution Management System(DMS)

Feeder Automation (FA)

Self Healing Network

Advanced Distribution Automation(ADA)


DA: What is it? Terminology and descriptions are

not yet standardized

Current IEEE Working Group

IEEE Draft Guide for SmartDistribution Applications Guide(P1854/D006, March 2017)

In basic terms, DA is…

a system

that enables an electric utility to

remotely monitor, coordinate andoperate distribution components

in a real-time mode from

remote locations

Source: IEEE Smart Distribution Working Group: Task Force on Distribution Management Systems (DMS)http://grouper.ieee.org/groups/td/dist/da/dmstf.html

Modern Grid With Automation

2–5 min. 20–30 min. 5–10 min. 1–5 hrs.

Traditional Grid Without Automation

5–10 min. 20–30 min. 15–25 min. 10–15 min. 1–5 hrs.

Unfaulted Segments Restored 50-80 min.


DA: Introduction

FaultOccurs

CrewSent

CrewTravel Time Find The

Fault

ManualSwitching

FaultRepair/Restore

Unfaulted Segments Restored<1 min.


DA: Automation SchemesMost common (Service Restoration):

Fault Detection, Isolation, and Restoration (FDIR)

Fault Location, Isolation, and Service Restoration (FLISR)

Sr1 Sr2B1 B2Sw1 Sw2 Sw3

N.O.

Zone 1 Zone 2 Zone 3 Zone 4

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DA: Automation SchemesFault Location, Isolation, and Service Restoration


N.O.


PermanentFault




N.O.


PermanentFault




N.O.


PermanentFault

Open Open

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N.O.


PermanentFault

Open Open




N.O.


PermanentFault

Open Open


DA: What does it do? “improves distribution network reliability by employing self-healing, smart

grid technology”

“improve both distribution network reliability and power quality for theconsumer while also optimizing asset life and the economy of powerdelivery for the utility”

“self-healing grids designed to improve reliability today while laying thefoundation for a grid that will meet future requirements as well”

“help utilities make more efficient use of their distribution systems …improves reliable power delivery, in turn it also improves utility customersatisfaction”

“increase system operational efficiency and reduce operating costs toaddress increasing customer expectations for affordable and reliableelectric service”

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DA: What does it do? “improves distribution network reliability by employing self-healing, smart

grid technology”

“improve both distribution network reliability and power quality for theconsumer while also optimizing asset life and the economy of powerdelivery for the utility”

“self-healing grids designed to improve reliability today while laying thefoundation for a grid that will meet future requirements as well”

“help utilities make more efficient use of their distribution systems …improves reliable power delivery, in turn it also improves utility customersatisfaction”

“increase system operational efficiency and reduce operating costs toaddress increasing customer expectations for affordable and reliableelectric service”


DA: What does it do? Improve System Performance

“Reliability”…

supply power demanded

reduce number of outages

“Resiliency”…

withstand suddendisturbances

reduce duration of outages

Improve Customer Satisfaction!

IEEE 1366…

Sustained Outage =Interruptions ≥ 5 minutes

Momentary =Interruptions < 5 minute


DA: What does it do?Primary Functions of DA

Fault Management

Load Management

Voltage / Loss Management

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DA: What is it?4 Key Physical Components

Measuring / Sensingdevices

Communication means

Computing / Dataprocessing

Controlling devices

Automate


DA: What is it made of?

Automate

Smart devices with sophisticatedcommunications network


DA: What is it made of? Measuring / Sensing devices

Stand-alone

EmbeddedAutomate Current

Position Status

Volt / Var

Located out onfeeder

Located inSubstation

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DA: What is it made of? Communication means

Fiber Optic

Radio

Cellular / WiMAX

Automate Mirrored bits

DNP3

GOOSE

Loop Scheme

Peer-to-Peer

2 way flow ofinformation

Typically most challengingcomponent!


DA: What is it made of?Communication factors to consider:

Coverage

Data Throughput

Latency

Direction

Availability and Reliability

Security

Cost


DA: What is it made of? Computing / Data processing

Controller(s)….the “brains”

Automated decision making

SCADA Master / Server…or LocalIntelligence

Remote Terminal Units (RTUs)

HMI

Automate

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DA: What is it made of? Controlling devices

SCADA control

Local controlAutomate Switches

Reclosers

VoltageRegulators

Feeder CB’s

Switched CapBanks


DA: When? Core Initiatives

System Planning Study

Critical Customers

Extreme weather events

High outage areas

Access problems…highresponse times

Tie-lines

Other CapEx / OpEx programs




DA: When? Momentary transients

Majority of the faults aretemporary

Lightning strikes

Downed trees/branches onoverhead lines

High wind causing contactbetween conductors

Bird / Animal contact



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DA: When? DER Integration

Increase in PVInterconnections

Planned generation/storageprojects

Outside funding

Flat or Negative Growth

Cost

Wide ranging and dependenton utility needs

Difficult to calculate ROI




DA: When? IEEE 1366 –

Standard for Reliability Reporting

C = No. Customers

CI = No. Customers Interrupted

MI = Minutes of Interruption

CMI = Customer Minutes of Interruption

SAIFI = CI/C (System Average Interruption Frequency Index)

CAIDI = CMI/CI (Customer Average Interruption Duration Index)

SAIDI = CMI/C = SAIFI * CAIDI (Sys. Avg. Interruption Duration Index)

MAIFI = MI * CI ÷ C

Sustained Outage =Interruptions ≥ 5 minutes

Momentary =Interruptions < 5 minute


DA: Challenges Communications Infrastructure

Cyber Security

Device Interoperability

Available CapEx/OpEx funds

Long term planning / study

Costly Build-out

Personnel training

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DA: Why? Reduce operational cost…Improve operational speed and accuracy

Deliver reliability improvements and cost savings to customers

Less effort required to operate / restore a system

Sensors provide early detection – allowing pro-active maintenance

Safer facilities and fewer forced outages


DA: In Recent News…

Source:https://www.utilitydive.com/news/duke-energy-to-harden-north-carolinas-power-system-with-13b-initiative/440524/

"When we improve our energy infrastructure, we not only improve powerquality and reliability for everyone, but we help grow our economy and createjobs while keeping energy at a reasonable price"

David Fountain,

Duke Energy's North Carolina, President


DA: Ancillary opportunities Other initiatives and services can work in concert with DA

implementation:

DMS

AMI / AMR

DER integration (“Customer Participation”)

Volt / Var optimization (VVO)

Conservation Voltage Reduction (CVR)

Load sectionalizing / balancing

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Source: Ruggedcom.net.ua

DA: Ancillary opportunities


DA: BriefMarket Drivers

Increasing investment in smart grids

DERs

Public Opinion / Participation

Market Challenges

High upfront cost

Complexity, Implementation

Market Trends

Emergence of IoT

Consumer focused programs

Take-Aways Traditional “Grid”

Reliable & Affordable

Cannot meet today’s demands

Modern “Grid”

Requires advanced technology

Real-time / Remote decision & control

Resiliency

Customer Participation


Distribution Automation

Improves Performance / Reliability

Key parts:

System Study / Plan

Measure

Communicate

Compute

Control

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Take-Aways “Enablers”

Commitment to Core Initiatives

System Planning Study

Strategic Deployment

Maximize Asset Utilization

Deferred CapEx

DERs

Funded Improvements

Public Opinion


“Disablers”

Cost…High ROI

Flat or Negative Growth

Radial Lines

Differing feeder voltages


DA: Technologies ComparisonSome DA Vendors in the Market(Alphabetically)

ABB

EATON

S&C Electric Company

SEL

Siemens

DA: Technologies Comparison


Response Time Decision Equipment Communications

1-5 minutes System Centralized,SCADA Master

Radio, Cellular Services

1 second –1 minute

Area/SubstationCentralized, AutomationPlatform, Relays

High-Speed/DedicatedRadio, Cellular Services,Fiber

< 1 second Local, Logic Processors,Relays

Fiber, Wired Connections

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Take-Aways Many different solutions on the market today.

One solution DOES NOT fit all.

Gain experience via small pilot project(s)

Investigate or try multiple solutions

Plan ahead, Integrate into your Long Range Plans

Share lessons learned with colleagues!


Automate

41© Booth & Associates, ILLC

237 Old Summerville Road, Unit HSummerville, SC 29486

(919) 851-8770

www.Booth-Assoc.com

Joshua W. Timm, PE

(919) 607-7817

[email protected]

Joshua W. Timm, PE

Distribution Feeder Automation:

Technologies Comparaison

© Booth & Associates, LLC. 42

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DA: Technologies ComparisonFLISR

Systems

http://new.abb.com/medium-voltage/distribution-automation

http://www.cooperindustries.com/content/public/en/power_systems/solutions/self-healing/yukon_feeder_automation.html

http://www.sandc.com/en/solutions/self-healing-grids/

https://selinc.com/solutions/distribution-network-automation/

https://w3.usa.siemens.com/smartgrid/us/en/distribution-grid/products/distribution-automation-systems/pages/distribution-feeder-automation-systems.aspx



Distribution Automation Systems solutions

RTU500 series system integration

Distribution Management System (DMS)

MicroSCADA Pro DMS600

Centralized at Substation (COM600)

Network Manager ADMS

IEC 61850 GOOSE

Wireless Communication – Tropos 6420

Protection & Control – Relion® 615 series



Yukon Feeder Automation (YFA) Software

Microsoft Windows® server-based application

Centralized data comm. architecture back to YFA

Works with many existing Intelligent ElectronicDevices (IED’s) via Standard open protocols(ie. DNP3, IEC 61850)

Flexible communications integration

Integrate with existing controls (ie. Form 6 reclosercontrol, SEL-351/351R, S&C 5801 auto-switch control)

GridAdvisorTM Series II integrate line sensor

Cellular modem, DNP3, simple SCADA visibility

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IntelliTeam® SG Automatic Restoration System

Distributed Intelligence, P2P architecture

Site Automation Testing / Emulator

SCADA compatible, but no SCADA control orcentralized monitoring required

IntelliRupter® PulseCloser® Fault Interrupter

voltages and currents measured at theswitching/fault-interrupting devices

reduces wear and tear

Compatible with S&C suite of devices/controls…and others

SEL 351s, Nu-Lec CAPM-5, Cooper Form 6, GE F60, and ABB Ref 550 Relays



Distribution Network Automation (DNA)

new Arc SenseTM technology (AST)

Distributed or Centralized control

Distribution Automation Controller (DAC)

RTAC, Library of objects

Recloser Control – SEL-651R

Volt/Var Control – SEL-734B w/ RTAC-3530

Voltage Reg Control – SEL-2431

Fault Transmitter/Receiver –

SEL-FT50, SEL-FR12 (Mirrored Bits)



Siemens Distribution Feeder Automation (SDFA)

Decentralized, peer-to-peer

Standardized IEC 61850 & DNP3 protocol

FLISR system programming in minutes

Graphical sequence programming software (FASE)

jDiffTM protection feature

Differential current to locate fault

Requires SDFA 7SC80 controllers

Protection and Automation, Optional HMI

Simulation & test mode

SIPROTEC 7SC80

Distribution Feeder Automation - MASC Associations/06-18... · Distribution Applications Guide...

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