Intelligent Line Monitoring and Disturbance Management€¦ · Ample Software Foundation for...
Transcript of Intelligent Line Monitoring and Disturbance Management€¦ · Ample Software Foundation for...
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Intelligent Line Monitoring and Disturbance Management Ryan Kelso/Justin Stroupe July 24, 2018
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New Braunfels Utilities Overview
¾41,373 Electric Meters ¾99.5% AMI (Itron Network Solutions) ¾160 sq. mi. Electric Territory ¾619 miles Primary OH ¾285 miles Primary UG ¾40 Distribution Feeders ¾20 miles of 138kV transmission ¾24/7 Control Center Operations
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The Desire
¾Enhance visibility of the distribution system ¾Improve system resiliency ¾Reduce outage duration - SAIDI ¾Lower outage frequency - SAIFI
¾Leverage existing AMI communications network to connect grid-edge devices
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Existing Tools
¾Fault Indicators (flashing lights) ¾Milsoft Outage Management System ¾Itron Network Solutions AMI ¾Intelligent substation relays
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The Solution: Sentient
$100+ million invested in developing and delivering
sensing technology
Proven technology ≈ 60,000 intelligent sensors shipped. Serving 8 of top 10 largest utilities in North America
Highest fidelity oscillography on the
market (>7,800 samples/second)
Multiple communications options
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MM3: Sentient Core Sensing Solution Overhead Feeder Monitoring System
¾ Continuously sampling, 130 Sample/cycle Current and E-field capture
¾ GPS for location and precision timing
¾ MM3 supports multiple communications options: Itron, L+G, and LTE technology
¾ Patented power harvesting technology requires no servicing or maintenance for the life of the product
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MM3 Intelligent Sensor
¾ Easy installation ¾ Local annunciation:
daylight-visible LED ¾ Embedded fault detection
algorithms: ¾Fixed Trip, Auto-range, Rate
of Change (di/dT) ¾ Inrush restraint, Loss Of
Source ¾ Event Details: ¾Fault magnitude, related
hi-res waveform
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Ample Software Foundation for Sentient’s Grid Analytics System (GAS)
¾ Complete sensor management ¾ Multiple DNP masters – directly connect to devices ¾ Analytics Software: ¾ Interval Logging - Current and Conductor Temperature per
phase ¾ Fault Location along the feeder and on what phase ¾ Phase Identification ¾ E-Field – monitors reverse flow of current ¾ Disturbance Management (Momentary/Incidents) –
Waveforms ¾ Easy to integrate ¾ APIs for historian integration ¾ Role level security
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Pilot Approach: 9 Sensors
¾Deployed 3 sets of sensors on 2 distribution feeders
¾Deployed at 2 substation feeder exits and 1 feeder midpoint
¾Developed ROI measurement ¾Value of Lost Load +
Operational Cost per SAIDI Minute
¾ Focused on disturbance management
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Disturbance Management what is a disturbance?
¾ A disturbance is a small and momentary change in current/e-field waveforms.
¾ Characteristics of a disturbance are: ¾ Disturbances usually do not cause a
sustained power interrupt ¾ Magnitude is usually 1-5 times normal
current (faults can cause > 15 times increase in current)
¾ Duration usually lasts less than 5 cycles (5 – 80 milliseconds)
¾ Distortions: 1st to 50 harmonic content (Sentient can detect up to 31st harmonic in underground solution)
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Pilot Results: Disturbance Management Trees grow into lines Control Center sees elevated
disturbance counts
Electric Ops finds tree
making contact with
B&C phase, trims
trees to prevent
outage, disturbances
return to normal
Avoided SAIDI: 2.66 min.
Avoided Cost: $16,770
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Change in workflow
Operator
receives fault
data from
Sensors
Runs fault
location tool
in OMS
Provides
operations
with
predicted
location of
fault
Operations
makes repairs
and reports
back results
for ROI
Calculation
Operator sees
fault
If fault data is
available
provide
prediction of
fault
Operations
will make
decision on
whether to
run out circuit
No report
usually
provided
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Calculating ROI
Avoided Costs(ROI) =
Value of Lost Load (VOLL) +
Operational Cost Per SAIDI Minute(OCPSM)
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Pilot Results
¾Delivered 2.66 SAIDI minute reduction through disturbance management ¾$16,770 in VOLL+OCPSM savings ¾SAIFI reduction
¾Communication through AMI network worked as designed
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Phase 2: 60 Sensors
¾Deployed 20 sets of sensors on 18 distribution feeders ¾Deployed on feeders with old
relays that did not report fault amplitude ¾Positioned at midpoint of circuit
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Benefits: Phase Identification
¾Identifies phase miss-match and reports detected phase
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Benefits: Phase Balancing
¾ Allow decision making based on facts not estimates
¾ Planning, load flow, dynamic loading application data
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Benefits: Disturbance Monitoring
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Benefits: Fault Detection ¾ Enables waveform capture, storage and analysis ¾ Precisely determine boundaries of disturbance using patent-pending algorithm ¾ Supports automatic or manual retrieval of waveforms ¾ Foundational component for disturbance analysis and event categorization ¾ Capture momentary and transient events for further analysis ¾ Instrument-class, sampling rate, “Oscilloscope on the wire”. True 130 samples/cycle.
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Benefits: Fault Locating 20
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Benefits: Temperature Monitoring
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Success
Predicted Location Actual Location
Fault Waveform
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Success
Faulted Element:
Broken Insulator
Cause: Lightning
Avoided SAIDI: 2.66 min.
Avoided Cost: $28,329.81
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Success
Issue Fixed on 7/20 – Disturbance counts fall off
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Phase 3: 66 Sensors
¾Currently deploying 22 sets of sensors ¾Deploying at feeder substation
exits to maximize coverage for disturbance management
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Results 26
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Results
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Results
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Results
¾Avoided SAIDI: 5.32 Minutes ¾Avoided Costs: $45,100.30 ¾Avoided Interruptions: 1,760 ¾SAIFI Reduction: 0.04 ¾Improved System Resiliency ¾Improved Customer Experience
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Lessons Learned
¾Deployment at substation feeder exit yields maximum disturbance management coverage ¾Get it in the hands of System
Operators early ¾Develop metrics, track and brag on
success – resulted in increased buy-in
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Future Plans
Continue deployment of MM3
Q3 2018: Pilot ZM1 “Low
Amp” Line Monitor
Q4 2018: Pilot UM3+ UG
Line Monitor
Q4 2018: Launch NBU
UAV Program
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Questions? 32