techadvantage 2015€¦ · •outage detection & location: provide better information to line...

Jim Weikert

Power System Engineering, Inc. www.powersystem.org

February 24, 2015

Building on What You Have to Improve Reliability through DA

TechAdvantage 2015

www.powersystem.org

© 2015 Power System Engineering, Inc.

Improved Outage Handling and Protection Many options are available today to assist with outages: • Outage Detection & Location: Provide better information to line

crews, customer service and operations. • Fault Investigation: Extract data easily to better recreate the source

of the fault. • Quicker Restoration: Reduce outage time for those who don’t

need to be affected by a fault. • Reduced Miscoordination: Consider reclosers which can address

miscoordination issues.

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Build on proven protection principals you have trusted for years.


Coordinated Outage Management

SCADA

AMI

OMS IVR

CIS

CVR (Meter Voltage)

SCADA Operator/Dispatch

Customer Service

Feeder Outages

Outage notification & verification

Usage (kWHr) & Disconnects

Customer

Outage alerts & updates

Power System Engineering, 2014

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GIS EA


Coordinated Outage Management Advanced metering infrastructure (AMI), together with SCADA and outage management systems (OMS), can also be used to locate permanent faults that result in outages

• SCADA detects fault current followed by current drop due to OCR operation.

• SCADA informs OMS of likely fault location. • OMS sends command to AMI to ping “bellwether”

meters at critical system junctions looking for an outage.

• OMS receives meter status from AMI indicating extent of outage.

• Operators use SCADA to isolate & restore other areas 4


Using Fault Location with DA – Example

Courtesy: Maquoketa Valley Electric Cooperative

• SCADA sees fault, highlights the line sections based on engineering model where fault could be located.

• AMI pings meters by sub/ckt/ph to determine extent of outage (green is on, red is out of power).

• 2-3 minutes later, know what is out of power.

• This case, knew that an OCR was out and the fault was located in highlighted region.

• Can even restore outages before members call.

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Fault Location & Event History Incredibly valuable relay data that should be retrieved: • Fault Location: Operations Data – display in SCADA

- Fault type: line-ground, line-line, phases involved - Fault current - Fault time - Distance to fault

• Event History: Engineering Data – oscillography - ¼ cycle data from relay - All currents & voltages - 30 to 60 cycles of data around fault time - Analyze with relay/recloser vendors tool

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Substation Relay Fault Data • First step is to get good fault data back from substation relays

– Direct communication with relays rather than through RTUs – Fault Currents have been used by many utilities to help line

crews find faults.

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Source High Side Low Side Main Feeder Analogs Fault Type F F F Fault Distance -- -- F Fault Current F F F Fault Recloser Shot Cnt -- -- F Fault Time F F F Status Trip Target F F F 50/51 Target F F F 87 Fault F -- -- A/B/C Phase Targets F F F Breaker Failure F F F Close Failure F F F Lockout F F F


Fault Information • The screen below provides an example of fault data from

a feeder relay that could be displayed on SCADA.

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Line Sensors / Fault Indicators • Traditional fault indicators were visual indicators for line

crews driving along a line. • New fault indicators provide fault and normal operation

information back to SCADA.

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Category Faulted Circuit Indicators High Resolution FCIs / Sensors Company PDP Eaton SEL GridSense Sentient OptiSense Product Smart Navigator Grid Advisor II WSO Line IQ MM3 Power Source Battery Line Current Battery Solar Line Current 120VAC @ Base

Battery Life 15 Year Several hour backup > 10 Year "x" hours

w/o sunlight Several hour

backup 9 hour backup

Communications

Sensor Local Wireless (100 ft.) Cellular from

Sensor

L+G or On-Ramp Wireless

from Sensor

Local Wireless (100 ft.)

Cellular, L+G, Silver Spring,

Cisco

Fiber

Base Station Ethernet Ethernet Ethernet

SCADA Support DNP from Base Station

DNP from Sensor

DNP from Head End

DNP from Base Station

DNP from Sensor

DNP from Base Station

Current Accuracy +/- 10% @ 20C +/- 20% over temp +/- 25% +/- 5% +/- 10% +/- 0.5% @ 25C

+/- 1.5% over temp

Waveform Data N/A N/A N/A 200ms / event (10 samples /

cycle)

Continuous (130 samples /

cycle)

Continuous (250 samples / cycle)

Fault Indication High intensity LEDs High Intensity

LEDs Reflective

Target High intensity

LEDs High intensity

LEDs N/A


Line Sensors & Fault Indicators Power Delivery Products

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Cooper

Grid Sense Sentient

• Wireless to base station • Fault data to SCADA • 10 year battery powered

• Cellular to control room • Fault data to SCADA • Line powered with battery

backup.

• Wireless to base station • Fault data to SCADA • Solar powered with

battery backup. • Waveform data saved

when faults occur.

• Cellular and other direct communications options.

• Fault data to SCADA • Line powered with battery

backup. • Waveform data captured

continually.


Benefits of Automated Restoration Best understood with an example: • Outage occurs on a feeder with 1,000 meters • Sequence of events without automation

– Detect outage (5 min) – Crews drive from home to office (30 min) – Crews drive from office to outage (30 min) – Crews sectionalize outage (15 min) – Crews repair fault (60 min)

• Sectionalizing reduces outage to 300 meters • Automation would allow operator to

sectionalize while crews are in transit.

Original outage

Sectionalized outage

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Restoration Levels

Category Process Time Frame Operator Activated Restoration

Detect trips with SCADA alarm, determine switching steps, coordinate with line crews, perform isolation & restoration

5 minutes

Centralized Automated Restoration

Software determines most likely fault location, isolation & restoration strategy.

5 sec – 2 min

Decentralized Restoration Recloser controls coordinate amongst themselves

1 – 30 seconds

Automatic Source Transfer Localized critical load source switching ~100ms (6-10 cycles)

Direct Transfer Trip Transmission Line protection between separate substations

~100ms (6 cycles)

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It’s critical to understand your end-goal for restoration before choosing an architecture to implement it. • Level of operator intervention and automation • Speed of restoration & available communications


Fault Handling & Restoration Steps Categories of Programs

• Substation Relays Fault Data: Getting information on fault type such as phases involved and fault currents can greatly aid in finding faults more quickly.

• Automating Feeder Equipment: The key to automating restoration is to upgrade feeder equipment so that it can provide important information and perform necessary operations.

• Operator Based Restoration: Once feeder devices are communicating with SCADA, operators can begin to assist crews, which can have significant improvements in reliability.

• Automating Restoration: Adding functionality to your SCADA to automate isolation and restoration is the ultimate step, though the improvement is incremental.

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Feeder Equipment Template • IED reclosers automated to support restoration • Reconfigured to alternate protection profile or switch mode • Protection Impact:

- At least 1 IED needs to remain in protection mode with alternate TCC - Tied point profile needs to protect customers on feeding segment - Fuses more likely to blow on radial feeders

Fault

Switch Profile

Alternate TCC Profile

TCC Profile

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Equipment Requirements for Automating Restoration

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Understand equipment impact for differing scenarios:

1. Isolating a Fault and Closing a Tie Point • Fault Detection: Recloser or Faulted Circuit Indicator • Isolation: Reclosers or Non-load break switches • Restoration: Reclosers or Non-load break switches

2. Balancing Load as Restoration Changes • Load Monitoring: Recloser or Faulted Circuit Indicator • Load Balancing: Load Break Switches

3. Impact on Protection Settings • In-line Hydraulic Reclosers: Settings for devices which

cannot be reconfigured need to be considered


Automating Switches • Typical recommendation is for reclosers at tie points to

isolate and avoid outage on unfaulted feeder • Load break and non-load break • Make best use of existing switches

– Motor operator (SEECO, Turner, …) – RTU – Faulted current indicators

• Determine fault for isolating • Monitor demand for load balancing

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Component Component Cost Total Motor Operator $6,500 Automation $13,500 - RTU $1,500 - FCIs $2,000 - Communications $5,000 - Enclosure / Battery / Wiring $5,000 Equipment Total $20,000


Fault Current Indicators • Get fault status and analog data and continuous current • Recommend DNP communication to bring directly into

SCADA. – Not a separate software for FCIs.

• Recommend private wireless communication – Cellular may not be reliable during outage.

• Consist of a base station / gateway and 3 FCIs

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Manufacturer / Model Wireless Option Protocol SEL – WSO L&G or OnRamp Cooper – GridAdvisor II Cellular DNP3 GridSense – LineIQ Bluetooth DNP3 Power Delivery Products – Smart Nav 2.4GHz DNP3

Base Station

FCI


Example Restoration Plan • Distant area would be good to speed

restoration. • Could be beneficial for members

south of South Park. • Fault along Feeder 508-2 from

Fairplay would normally cause an outage to these members. – Fault would trip 3-phase hydraulic OCRs – Isolate from fault with S214 (verify no

fault seen here) – Close S239 to back feed from Hartsel

substation. – Intelligent recloser on feeder 105-3 has

adaptable protection settings and would protection rest of Hartsel substation from fault when closing S239.

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508-2

105-3

Tie Point (S239)

Isolate (S214)

Isolate (Nova TS)

Fault

Trip

R

R


MotoTRBO DA Communications – Overview

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• Motorola ACE RTUs interface with SCADA and IEDs to send data over the MotoTRBO system. – XPR 5350 Radios used to send data as a call over LMR network. – Number of Devices depends on settings. Recommend ~50 devices per

talk channel in an area with ~ 5 second delay for data. – Cost of approximately $6,000 at the feeder device.


Example Restoration Plan • Potentially save 1-2 hours of outage

for several hundred members. • Equipment Upgrades of ~$43,000

– Motor Operator and FCI for S214 – Motor Operator and FCI for S239 – Communications for Nova TS

• Additional work to integrate – Engineering to verify protection and

regulator settings. – Program ACE RTUs

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508-2

105-3

Tie Point (S239)

Isolate (S214)

Isolate (Nova TS)

Fault

Trip

R

R Equipment Cost

S214 MO & FCI $16,000 S239 MO & FCI $16,000 Nova TS Communication $6,000 Contingency $5,000 Equipment Total $43,000


Decentralized FDIR Overview • Roles

– Devices communicate directly and make decisions – SCADA Operator monitors and override if necessary.

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• Requires common devices – Reclosers must have

same decision making algorithm.

• Most appropriate when deployed for targeted restoration areas. – Groups of devices

making local decisions


SCADA to a Distribution Management System • Centralized FDIR expands SCADA into a DMS • SCADA

– Controlling your substations – Monitor line currents – Alarms indicating breaker trip, etc.

• Distribution Management System

– Control your distribution system – Locate faults on distribution lines – Modeling your feeders – Feeder voltage prediction

(network stability) – Feeder voltage management (VVO)

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Modeling Automated Restoration • The “model” is the set of information that the software uses to

make decisions. • It impacts what decisions the software can make.

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Full Electrical Model Device Parameter Model

• Easier to configure. • Can dynamically adjust load to

allowable current levels. • Cannot predict end-of-line voltage.

• Import WindMil or other engineering model.

• Supports dynamic load balancing and end of line voltage prediction.

• Based on load prediction.


Operator Interaction • Key aspect to a centralized FDIR is the ability for

operators to actively participate in the restoral process. – Verify Switching Orders – Red-line system changes – Planning & Operator Simulation

• Indicate Faults and observe switching recommendations from system.

• Perform switching and model system voltages under various loads.

– Crew Interaction • Applying Hot Line Tags when crews are working on line

segments. 24


Centralized & Decentralized Considerations • Goals

- Operation interaction: control, approve or monitor - Speed of restoration: minutes or seconds - Model-based or parameter-based system - Multi-vendor recloser support

• Situation

- Speed of communications - Distance between reclosers and coordination - Capabilities of your existing SCADA system - Coordination with your power supplier

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Switching Example – System Diagram • Bolt-on configuration

– SCADA Master – Yukon Feeder Automation processing feeder information – Preferred in that YFA is only processing restoration information and

not all switch diagnostic and status information

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Safety & Automated Restoration Hot-Line Tags:

• Lineman or SCADA operator places a hot-line tag on a recloser • Crew safety is the primary goal for workers on attached lines • Recloser changes to “single-shot to lock-out” • Automation changes:

- No restoration on any circuits attached to a device with a hot-line tag - SCADA cannot close an open device which has a hot-line tag on it

Apply HLT

No Restoration Fault Occurs

SCADA can’t close

Before Restoration Limited Restoration 27


Distribution Automation Summary Outage Handling • Goals:

– Improved Operational Efficiency – Improved Customer Satisfaction

• Understand what restoration time frame desired • Consider capabilities of current SCADA • Consider capabilities of reclosers and feeder switches • Communications available

Secure Communications • Communication performance determines DA performance • Fit the technology with the application and environment • Securing your DA network restricts access to your entire system • Get the benefits built into protocols

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© 2015 Power System Engineering, Inc. 29

Power System Engineering, Inc. Jim Weikert Lead Utility Automation Consultant Direct: 608-268-3556 Mobile: 608-206-3753 Email: [email protected] www.powersystem.org

Thank You:

mailto:[email protected]

techadvantage 2015€¦ · •outage detection & location: provide better information to line...

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