improving distribution circuit performance without circuit ... · case study: unitil (t&d...
TRANSCRIPT
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Improving Distribution CircuitPerformance without Circuit Rebuilds
John Lauletta, CEO
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Maintenance StrategiesReliability Centered
Maintenance
ReactiveMaintenance (Run
To Failure)
PreventiveMaintenance (Time
Based)
PredictiveMaintenance
(Conditions Based)
ProactiveMaintenance
(Improvement)
• Small, non critical items• Inconsequential,
not likely to fail• Redundant
• Subject to wear• Consumable• Known failure pattern
• Random Failure Pattern• Not Subject to wear• PM Induced Failures
• Root Cause FailureAnalysis (RCFA)
• Failure Mode EffectsAnalysis (FMEA)
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Predictive Maintenance (PdM)• To use data from an entire process to find any measurable
characteristics that may serve to warn that these detrimentalsituations are approaching.
• PdM techniques are designed to help determine the condition of in-service equipment in order to predict when maintenance should beperformed. This approach promises cost savings over routine ortime-based preventive maintenance, because tasks are performedonly when warranted.
• PdM inspections are performed while equipment is in service,thereby minimizing disruption of normal system operations.Adoption of PdM can result in substantial cost savings and highersystem reliability.
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Predictive Maintenance (PdM)
Visual Inspection
Infrared Detection
Ultrasonic DetectionRF Emission Grid Inspection
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Impacts of Maintenance Strategies
Early FailurePeriod
Constant FailurePeriod
Wear-out FailurePeriod
Failu
re R
ate
Periodic/PreventiveMaintenance
PredictiveMaintenance
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PdM – How?• To evaluate equipment condition, predictive
maintenance utilizes non-destructive testingtechnologies such as infrared photography,ultrasonic acoustic, radio frequency (RF)emissions, corona detection, vibrationanalysis, sound level measurements, oilanalysis, and other specific online tests.
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PdM Why? Benefits of PdM Strategies• Maintenance costs - down by 50%• Unexpected failures - reduced by 55%• Repair and overhaul time - down by 60%• Spare parts inventory - reduced by 30%• 30% increase in machinery MTBF• 30% increase in uptime
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Applying a PdM Strategy to the Grid
1. Assess System Condition2. Schedule Maintenance3. Measure Results4. Repeat Process
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Animals18%
Miscellaneous19%
U.S. Non Weather-Related Outages on the ElectricDistribution System
Data Source:
32% of outagesare caused by trees
31% of outagesare caused by
failing equipment
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Animals18%
Miscellaneous19%
Maintenance Techniques
32% of outagesare caused by trees
31% of outagesare caused by
failing equipment
Data Source:
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Detecting Equipment Failure
Device• Insulator
FailureMechanism
• Internal Damage• Contamination• External Damage• Dry Band Arcing• Leakage• Tracking
FailureMechanism
Failure Detection TechnologyRF US-AC IR
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Detecting Equipment Failure
Device• Lightning
Arrester
FailureMechanism
• MOV Damage• Contamination• External Damage• Dry Band Arcing• Leakage• Tracking
Failure Detection TechnologyRF US-AC IR
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RF US-AC IR
Detecting Equipment Failure
Device• Cutout
FailureMechanism
• Internal Damage• Contamination• External Damage• Dry Band Arcing• Leakage• Tracking
Failure Detection Technology
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Detecting Equipment Failure
Device• Transform
er FailureMechanism
• Bushing Damage• Contamination• Internal Arcing• Low Oil
Failure Detection Technology
RF US-AC IR
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Detecting Equipment Failure• Use Technologies that measure specific failure
symptoms• Apply Technologies in most cost-effective
manner• Manage conditions-based analytics for
proactive maintenance action
Technical Tutorials
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Case StudiesUtility Experience with PdM Programs
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Case Study: PG&E (EEI TD&M, Oct, 2016)
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Case Study: UNITIL (T&D World, Oct. 2015)
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Case Study: COSERV (RE Magazine,Oct. 2016)
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1. Patented Radio Frequency (RF) Technology– Captures PD & EMI emissions present in the field– Correlates emissions with GPS location
2. Proprietary Analysis (Failure Signature Library)– Analyzes and discriminates field data to identify specific
structures where arcing, leaking, & tracking are present
3. Ultrasonic Acoustic Technology– Field Engineers visit identified structure– Pinpoint component responsible for problematic conditions
Predictive Process
Exacter’s predictive process utilizes two technologies andproprietary analysis to identify non-temporary & consistent,problematic conditions that are related to the overheadelectric system
Process & Technologies
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Exacter Radio Frequency Assessment
Failure Signature Analysis• Analyze & Discriminate Field Data• Identify emissions related to overhead
system• Specific location where PD/EMI is
present
• Data collection• Capture Partial Discharge & EMI• Correlate with GPS• Multiple passes
• Non-temporary• Consistent
Process & Technologies
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The 1,161 RED FailureSignature Events are
captured by the EXACTERRF Assessment.
The Failure SignatureAnalysis identified 77 BLUE
Maintenance Groupswhere problematic
conditions (PD/EMI) arepresent.
Exacter Process & Technologies
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Ultrasonic Field Locating
Exacter Process & Technologies
• Exacter Field Engineer visit identifiedstructure
• Confirm presence of PD/EMI• Identify specific component(s) responsible
for problematic condition
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Deteriorated Equipment Population(7 year, 2 million structure survey)
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U.S. Lightning Density
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Regional DeterioratedEquipment Findings
KCP&L Located Equipment
Transmission Posts2%
Transformers2%
Dead Ends12%
Insulators4%
Lightning Arrestors7%
Cutouts3%
Pin Insulators69%
Misc HW1%
Lightning ArrestorsCutoutsDead EndsMisc HWPin InsulatorsInsulatorsTransformersTransmission Posts
Progress Energy Florida — Located Equipment
Non-Utility2%
TransPost Insulators
6%
Transformers6%
DistPost Insulators
15% Lightning Arrestors55%
Ground2%
Pin Insulators10%
Dead Ends4%
Lightning ArrestorsGroundTransformersDead EndsPin InsulatorsDist Post InsulatorsTrans Post InsulatorsNon-Utility
APS Located Equipment
Transmission Posts10%
Transformers4%
Dead Ends16%
Insulators4%
Lightning Arrestors13%
Cutouts10%
Pin Insulators42%
Misc HW1%
Lightning ArrestorsCutoutsDead EndsMisc HWPin InsulatorsInsulatorsTransformersTransmission Posts
Western Located Equipment
Transmission Posts14%
Transformers3%
Dead Ends14%
Insulators6%
Lightning Arrestors0% Cutouts
6%
Pin Insulators57%
Misc HW0%
Lightning ArrestorsCutoutsDead EndsMisc HWPin InsulatorsInsulatorsTransformersTransmission Posts
Baltimore
Lightning Arrestors17%
Cutouts2%
Deadends3%
Misc HW2%
Pin Insulators74%
Insulators0%
Transformers0%
Grounds2%
Lightning Arrestors
Cutouts
Deadends
Misc HW
Pin Insulators
Insulators
Transformers
Grounds
Baltimore
Lightning Arrestors4% Cutouts
12%
Deadends7%
Misc HW7%
Pin Insulators55%
Insulators4%
Transformers4%
Grounds7%
Lightning Arrestors
Cutouts
Deadends
Misc HW
Pin Insulators
Insulators
Transformers
Grounds
Transmission Posts2%
Transformers2%
Dead Ends12%
Insulators4%
Lightning Arrestors7%
Cutouts3%
Pin Insulators69%
Misc HW1%
Lightning ArrestorsCutoutsDead EndsMisc HWPin InsulatorsInsulatorsTransformersTransmission Posts
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Hidden Damage – No Protection
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Obvious Physical DamageNo Protection Deterioration
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Laboratory Specimen Test Setup
Arrester UnderTest
Antenna Arrayand Ground
Plane
RF EmissionInstrumentation
Adjustable HV ACSource
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Comparing New andDeteriorated Arresters
• Current SensingResistor is 25 ohms
• Resistive voltagedivider = 1000/1
• Leading current istypical until cutoffvoltage is reached
• 58 Field samples werereviewed
New Specimen
Deteriorated Specimen
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RF Emission Spectrum
• Linear Frequencyscale 0 to 1.5GHz
• Historical andInstantaneousanalysis shown
Deteriorated SpecimenEmission Spectrum
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Demodulated RF Emission Analysis
Condition Signature Development
Onset of FailureSignature @ 0.67
MCOV
End of RF Signature@ 0.56 MCOV
Sensor correlatesdemodulatedemissioncharacteristics tofailure signature
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Central Texas Service Territory• 6 counties
190,000+ customers served
4,600 Distribution Miles• 2,200 Overhead Miles• 2,400 Underground Miles
Case Study – South Central U.S.
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Data Analysis: Historical Interruption Data
The customer provided the most recent 12 months of interruption data– October 1, 2013 – September 30, 2014
• IEEE Equipment Cause Codes:• 300 – Material or Equipment Failure
• 400 – Decay/Age of Material or Equipment
• 410 – Corrosion/Abrasion of Material or Equipment
Outage Cause CMI # ofInterruptions % of CMI
Equipment 1,619,925 85 33% (Approx)
** Excludes IEEE days for MEDs // Excludes Momentaries
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Data Analysis: Exacter Pareto Analysis
• Exacter Analysis normalizes the dataset to allow formeaningful comparison of the circuits
– Divide Total EQ CMI / OH Miles for each circuit
– The new metric used to compare circuits is Equipment CMI / OHMile
• Exacter ranks each circuit by the Equipment Related CMI /OH Mile
– Circuits with the highest Equipment CMI / OH Mile provide thegreatest opportunity to improve performance and reliability
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Data Analysis: Exacter Pareto Analysis
Feeders that representgreatest opportunity forimprovement
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2015 Pilot Assessment
The pilot covers portions of 67 circuits totaling 180 miles ofoverhead distribution
- The majority of overhead miles are 3-phase infrastructure- Eastern area of Service territory- High growth area
The option has the opportunity to impact 993,338 equipmentrelated customer minutes of interruption (CMI)
- 29 Equipment related outages
Circuit Selection
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2015 Pilot Assessment Area
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2015 Pilot Assessment: Equipment Findings
Survey Results
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2015 Pilot Assessment: Component Finds
• Exacter assessment identified 1 component every 2.68 miles– 3-phase overhead // co-located circuits // overbuild
– Density of service territory
– Presence of protective devices on system
• Exacter assessed 6,446 poles– 180 assessed miles = 6,446 poles
– 67/6,446 = 1.03% of poles with problematic conditions
– 98.97% of assessed infrastructure does not have presence of problematic conditions
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2015 Pilot Assessment: Field Report
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2015 Pilot Assessment:Considerations & Conclusions
• May 2015: “Wettest” month on record for Dallas-Ft. Worth area– 4.4 million lightning strikes
• More than 2013 or 2014 total
• Correlate lightning strike data with Exacter assessment
• Maintenance Operations for Identified Components– Further Lightning Arrester investigation
• Identify use for Exacter assessments in future maintenance operations
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Summary and Remaining Work
• Arresters are a critical component in electric grid equipmentreliability
• Arresters are most deteriorated in areas of greatest need:Southeast/Northeast U.S.
• Visual damage is not typically apparent and does not necessarilyindicate state of protection element
• RF emissions characterize deterioration that impacts performance• In 58 samples, 57 showed deterioration of protective ability• More field samples will be evaluated in laboratory conditions to
optimize failure signature discrimination and source location forutility maintenance planning