Post on 13-Mar-2018
Realizing Reliability Benefits of Distribu5on Automa5on:
Early Impacts & Lessons Learned Joseph M. LoPorto, PE
Manager, T&D Automa9on February 20, 2014
American Recovery and Reinvestment Act of 2009 • Smart Grid Investment Grant Program • Smart Grid Demonstration Program
For further information go to www.smartgrid.gov.
The information in this presentation is based on the results of a DOE funded project under:
or the
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Acknowledgement "This material is based upon work supported by the Department of Energy under Award Numbers: DE-OE000300, DE-OE0000301, DE-OE0000204” Disclaimer: "This report was prepared as an account of work sponsored by an agency of the United States Government. Neither the United States Government nor any agency thereof, nor any of their employees, makes any warranty, express or implied, or assumes any legal liability or responsibility for the accuracy, completeness, or usefulness of any information, apparatus, product, or process disclosed, or represents that its use would not infringe privately owned rights. Reference herein to any specific commercial product, process, or service by trade name, trademark, manufacturer, or otherwise does not necessarily constitute or imply its endorsement, recommendation, or favoring by the United States Government or any agency thereof. The views and opinions of authors expressed herein do not necessarily state or reflect those of the United States Government or any agency thereof."
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4 PEPCO HOLDINGS, INC. All rights reserved.
Presenta5on topics • PHI Quick Facts • Automa5on Technologies • ASR Overview and Demonstra5on • Es5mated Impacts On Reliability • Learnings from ASR pilot project and ini5al SGIG projects.
• ASR commissioning 5meline • Summary of Benefits • Q&A
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Pepco Holdings, Inc. Quick Facts • Incorporated in 2002 • Service territory:
8,340 square miles • Customers served (~2M)
– Atlantic City Electric: • 545,000 – electric
– Delmarva Power: • 503,000 – electric • 125,000 – natural gas
– Pepco: • 793,000 – electric
• Total Population Served: 5.6 million
• Regulated transmission and distribution is PHI’s core business
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Distribu5on Automa5on (DA) Project Types
• Automa9c Sec9onalizing & Restora9on (ASR) Schemes – DA ASR entails the installa5on of certain devices that are intended to work together to iden5fy
distribu5on feeder faults, automa5cally isolate iden5fied faulted area, and reroute electricity supply to segments of the outage feeder un-‐impacted by the fault. This will to reduce the number and length of electric system outages, resul5ng in increased reliability and customer sa5sfac5on.
• Dissolved Gas Analysis (DGA) monitors on substa9on transformers – This on-‐line system will con5nuously monitor eight cri5cal fault gases and other transformer
insula5ng oil key parameters for a 5mely assessment of transformer condi5ons to schedule maintenance and help prevent failures.
• URD Fault Detectors System –FDS (Pepco MD) – This system will iden5fy the loca5on of faulted URD transformers by conveying a signal back to
the control center in order to reduce 5me spent by crews in loca5ng faults. • Network Transformer Protector Remote Monitoring System -‐ RMS (Pepco DC)
– This system will provide real 5me remote control/monitoring capability as well as power quality informa5on such as phase currents, transformer loading, power factor, etc. to network transformers through implementa5on of two way communica5on and installa5on of intelligent sensors for an enhanced reliability of the network system.
• Capacitor Bank Automa9on – This project will add feeder capacitors that have supervisory controlled capability and
visibility. This will allow remote control of feeder reac5ve power (VAr) and resolu5on of high/low voltage issues.
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ASR Overview – Building Blocks • Smart Relay/Smart Meter: A substa5on feeder terminal device that measures
opera5on aWributes of a feeder and is used for coordina5ng feeder protec5on at the substa5on.
• Distributed Remote Terminal Unit (DRTU): A substa5on system which cons5tutes of a CPU, ethernet switches, circuit breaker controllers, and a data concentrator, all which work together to provide the electronic link to the control center, and breaker status to the ASR Control System.
• ASR Control System -‐ Substa5on computer and control program that monitors the status of the field devices and coordinates their opening and closing to isolate the fault and restore service to un-‐impacted feeder sec5ons.
• Automa9c Circuit Recloser (ACR): A feeder line protec5ve device which opens/closes when it detects fault current or through remote/local command to isolate a feeder sec5on. This device can reclose mul5ple 5mes to ride through temporary faults.
• SF6 Switch: A feeder line switch which opens/closes either through remote or local command to isolate a sec5on of feeder circuit. This is not used as a protec5ve device.
• Electronic Controllers – Each device above has an electronic controller that allows seYng of opera5on commands, local opera5on of the device, and with added communica5on, remote opera5on of the device.
• Remote Radio: equips each field device controller with remote control capabili5es through the wireless mesh network.
• Repeaters-‐Relays. Radio Masters. Access Points: Cons5tute the wireless mesh network which transmits field data to the intended des5na5on in the data network, and back again.
Sub
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Aut
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Feed
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PHI’s ASR System • Protects customers from sustained outages caused by feeder lock-‐outs
• Segments feeders into 2, 3, or 4 sec5ons using closed remote controlled SF6 switches or Automa5c Circuit Reclosers (ACR’s) in the field
• For an fault in any one sec5on, ASR opens closed switches to isolate the sec5on
• ASR restores the other sec5ons by reclosing the feeder breaker and/or closing open 5e switches to other feeders
• Generally ASR operates in less than a minute
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ASR System -‐ Demonstra5on
Substation
Fault Occurs on Feeder 001
Feeder 001 Locks out
1008 Customers out
ASR verifies switch status and fault location
Open Switch
Open Switch
Close Switch
270 Customers out
Total Time: 51 Seconds
Close Breaker
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Outage impact reduc5ons (Pilot ASR scheme)
• 4 fdr scheme • 6,800 CI Saved • 1.2 Million CMI Saved • 181 min ave dura5on of saves • 20-‐50% rel Impr possible
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Outage impact reduc5ons (DOE Scheme 1)
• 16 fdr scheme • 10,500 CI Saved • 1.4 Million CMI Saved • 136 min ave dura5on of saves • 20-‐50% rel Impr possible
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Some reasons for non-‐opera5ons
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• As designed: maintenance/repair work, downed conductor, system operator discre5on.
• Addressable: equipment failures, telecom failures, false fault targets, process issues.
Learnings/Recommenda5ons -‐1
• Iden5fica5on of resources up front is key to comple5ng the work on 5me. Include all skill sets: planning/PM, engineering, construc5on, tes5ng/ EMS integra5on, and maintenance.
• Lab modeling/tes5ng is essen5al to reduce implementa5on errors – Validate interoperability and network connec5ons – Adjust for un-‐modeled aspects (e.g., tree foliage) per experience with completed projects.
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Learnings/Recommenda5ons -‐ 2
• New class of assets will not follow tradi5onal asset lives. (e.g., 15 years Vs. 30 years)
• Incorporate cyber protec5on from the beginning of the project: – Apply access control, firewalls, encryp5on, etc – Work with vendors to develop applica5on level encryp5on for distribu5on equipment.
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Learnings/Recommenda5ons-‐ 3 • Smart devices are subject to more frequent firmware upgrades/revisions – Can occur during project implementa5on – Prepare for the increasing numbers by moving towards remote “over the air” upgrade capabili5es.
• Con5nued maintenance is cri5cal – can’t just set it and forget it! – BaWery failure most common maintenance issue; add dual power
sources to the controls. Develop baWery replacement program. – Communica5on system needs to stay con5nuous; NOC plays a key
role. – DA models need to stay up to date; iden5fy and train stake holders. – Add adequate funding for maintaining equipment and systems
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ASR Commissioning Timeline:
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2014 & Beyond
2012 2013
Install substation and feeder smart devices , and telecom infrastructure
2011 2010
MD: ASR 1 commissioned DC: ASR 2 commissioned ACE: ASR 3 Commissioned
Initiate DOE SGIG Distribution Automation
MD: ASR 4 Commissioned DC: ASR 5 Commissioned MD: ASR 6 Commissioned ACE: ASR 7 Commissioned MD: ASR 8 Commissioned MD: ASR 9 Commissioned DC: ASR 10 Commissioned
DA continues with additional ASR schemes & other reliability improvement technologies.
• SGIG project for 113 feeders has been completed • ASR for an additional 12 feeders in DPL service area also completed. • Together with 6 other ASR feeders, PHI now has 131feeders (utilizing 475
field devices) completed.
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Summary of DA/ASR Expected Benefits
• Distribu5on Automa5on will help PHI achieve its smart grid vision.
• It will result in key benefits to customers and the company: – Improved feeder and system reliability à increased customer sa5sfac5on
– Increased visibility, control, and op5miza5on of the distribu5on system.
– Opera5onal savings from reduced field trips and restora5on 5mes.
– Increased knowledge of transformer health resul5ng in beWer maintenance and asset end of life control.
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