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TRANSCRIPT
System Modernization and
Reliability Project (SMRP)
Presenter: Michael Smalley, principal engineer – WEC Energy GroupCo-authors: Steven Schott, Ross Barrette, Michael Smalley
IEEE ICC Education SessionOct. 23, 2019
System information
• 446,000 electriccustomers
• 98% of electricalsystem is 24.9 kV
• ASCC: 3,600 amps,RMS, Sym.
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Project background
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SAIDI comparisons
6-year SAIDI average (336.39)was higher than averages of otherstate utilities over the same period(160.17 minutes)
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Customers that experience an outage bynumber of outage events per year
Outage comparisons by territory
• 33,167 customers (7.6%)experienced an average of5+ outages per year
• 72% of those outages were locatedin high density forest areas
• 5,413 customers (1.2%)experienced an average of10+ outages per year
• 90% of those outages were locatedin high density forest areas
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Lines to be replaced
• Distribution feeders are radial
• Typical 24.9 kV distribution feeder in rural areas canrun up to 50 circuit miles in one direction
• Advantages– Fewer substations
– Improved voltage profile
– Fewer losses
• Disadvantages– Longer radial lines
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SMRP Phase 1
• Optimize performance and cost
• Reliability improvement of 25%
• Move from 3rd/4th quartile to 2nd
quartile
• Add distribution automation –400 miles
• Replace overhead primarydistribution with underground,focus on areas and feederswith the worst SAIDI (1,000 to1,200 miles over 5 years)
• Total project cost $218 million
• Construction in 2014-2018
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SMRP Phase 2
• Additional 960 miles underground
• No distribution automation
• Reliability improvement of 17%
• Project cost $211.5 million
• Construction in 2018-2021
• Yes, we’re in Phase 2 already!
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Project cycle
Begin to contact customers andgauge overall interest in project
Begin field design, asset collectionand construction print creation
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Staking and construction
Identify and prioritizeoverhead circuits that wouldprovide maximum reliabilitybenefit for cost investment
Environmental walk-throughs
General permittingand applications
Send out easement drawings to customersand begin to acquire necessary easements
Complete as-builtsand update GIS
Removal of existingoverhead facilities
Project challenges
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• Safety
• Customer communications
• Easement obtainment
• No locates for design
• Environmental constraints
• Weather – local andnationwide
• Other in-ground facilities
• Rock
• Availability of skilled workforce
• Contractors performingenergization and cutovers
• Installation quality (PD testing)
• Indian reservation construction
• Wood turtle
• Bald eagle
• Osprey
• Loggerhead shrike
• Red shouldered hawk
• Little brown bat
• Hine’s emeralddragonfly
• Blanchard’s cricketfrog
• Spruce grouse
• Cerulean warbler
• Eastern ribbon snake
• Black tern, Foster’stern
• Kirtland’s warbler
• Hooded warbler
• Henslow’s sparrow
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Threatened and endangered animals encountered
Environmental monitoring
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SMRP safety performance to date
• 1,200,000 hours of installation
• 7 OSHA incidents
• 2 lost time incidents
• OSHA RIR = 1.19
• Industry avg. RIR = 2.80
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Installation techniques
• Open cutting (2%)
• Plowing (50%)• Vibratory plowing(>75%)
• Plug plowing (<25%)
• Boring (48%)• Directional
• Pneumatic boring
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Vibratory plowing
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“Plug” plowing equipment
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Typical distribution automation (DA) scheme
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TotalPhase I & II
1994 382 434 155 (46%)
SMRP YearMiles URD
cableMiles main line
w/DASpend
(million $)
ProjectedSAIDI
(minutes)
Phase I
2012-2013 - - 6 -
2014 203 48 33 18
2015 229 103 47 19
2016 228 78 56 22
2017 283 99 61 23
2018 151 54 39 10
Phase II
2017 - - 2.5 -
2018 137 - 18 6
2019 274 - 64 26
2020 273 - 64 14
2021 216 - 35 17
2022 - - 2 -
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System Modernization and Reliability Project
• 2014-2021 segments replaced with underground cable (all districts)
• Percent improvement 16% outage events
34% CMI
11% CI
Actual 2017outage events
Avoided 2017outage events
Actual 2017customerminutes ofinterruption(CMI)
Avoided 2017customerminutes ofinterruption(CMI)
Actual 2017customersinterrupted (CI)
Avoided 2017customersinterrupted (CI)
8,986 1,410 215,148,840 72,000,000 508,521 60,000
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System Modernization and Reliability Project
• 2014–2018 distribution automation schemes (all 13 schemes)
• Percent improvement 0% outage events
2% CMI
8% CI
Actual 2017outage events
Avoided 2017outage events
Actual 2017customerminutes ofinterruption(CMI)
Avoided 2017customerminutes ofinterruption(CMI)
Actual 2017customersinterrupted (CI)
Avoided 2017customersinterrupted (CI)
8,986 0 215,148,840 6,000,000 508,521 36,000
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System Modernization and Reliability Project
• Total SMRP underground installation and distributionautomation
• Percent improvement 16% outage events
36% CMI
20% CI
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System Modernization and Reliability Project
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Additional estimates for PH I (2014–2018)
• 1,015 route miles of primarycircuit
• 2,533 actual miles of primarycable
• 80 route miles of secondary
• 128 miles of secondary cable
• 6,400 easements
• 3,680 new undergroundservices
• Warehousing materialthroughput doubled for entireWPS company
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Slide 26
A2 secondary circuit?Author, 10/31/2019
SMRP cable system materials
• 1 PH transformer (15, 25 and 50 kVA)• Set on fiberglass box pads
• But flat pads not completely off the table yet
• Formerly included under oil arresters; now using elbow arresters
• Joints• Cold shrink with integral metallic shield and jacket exclusively• Some push-on joints were used in earlier years of PH 1• Recently converted CS joints to 100% shear bolt connectors
• Terminations• 100% cold shrink silicone rubber terminations
• Separable connectors• 200 A loadbreak• 600 amp dead break having 200 bushings for testing and grounding
purposes
• Junction enclosures – fiberglass• 200 A and 600 A
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SMRP materials – cable
• Cable sizes/designs (all use 100% insulation levels)• #1 Sol Al (full neutral) 25 kV JCN – most common cable used
• #4/0 Strd Al (90% neutral and 1/3rd neutral) 25 kV JCN
• 750 kcmil Al (1/6th neutral) 25 kV JCN
• Basic cable design as shown below:
• Note: Insulation mostly TRXLPE, but EPR also used
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Solid or sealedconductor
Interesting SMRP facts
1. Contract installers are certified for installation of cableaccessories before working on-site.
2. Shunt reactors are sometimes employed on long cablelengths to control the “Ferranti effect” due to cablecapacitance.
3. When PSCW approved the project, use of unjacketed(bare) concentric neutral cable was allowed (and used).
• BCN cable no longer being installed.
4. On application for the CA, expected life for new cablewas indicated as:
60 years
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Some examples of what we find:
SMRP materials – new cable inspection
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New cable inspection data
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Inspecting new cable allows usto monitor trends in cablemanufacture with time such as:
• Cable insulation thickness
• Eccentricity
• Insulation cure
Project challenges
• No. 1 quality risk identified asterminations and splices
• Put into place a system to holdcontractors accountable• Partial discharge (PD) testing for all
personnel doing terminating
• Over 2,000 terminations/splices/riserstested
• One cable failure – due to backfillmaterial, one splice failure
• Contractors initialize each device theyterminate
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Partial discharge (PD) testing
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Questions?
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