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Smart Urban Low Voltage Network Low Carbon Network Fund Tier 1 Project

Smart Urban Low Voltage Network Low Carbon Network Fund Tier 1 Project. UK Power Networks & TE Connectivity. Project Background. Follow-on project after successful IFI trials. IFI project aims: Develop a new solid-state switching technology for use on the LV distribution network.

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Smart Urban Low Voltage Network Low Carbon Network Fund Tier 1 Project

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  1. Smart Urban Low Voltage NetworkLow Carbon Network Fund Tier 1 Project UK Power Networks & TE Connectivity

  2. Project Background • Follow-on project after successful IFI trials. • IFI project aims: Develop a new solid-state switching technology for use on the LV distribution network. • LV Remote control and automation system utilising retrofit switching devices to be installed and trialled on LPN LV network. • Project registered in July 2012 – Project aims: - Undertake a large scale demonstration of technology developed in the IFI project. - Explore the benefits provided by an integrated LV remote control and automation system. Active Network Management Improved safety Maximise utilisation of plant Enhanced network modelling / planning Quality of Supply improvements

  3. LV Remote Control & Automation– System Component Devices At the distribution substation Installed to LV Link Boxes RTU (Remote Terminal Unit) provides remote control of the LV devices. Load-break / fault-make switches replace solid links in LV Link Boxes Single phase fault-break / fault-make circuit breakers (CB) retrofitted in place of the existing LV fuses. Local control of switches provided by a control panel (fits under LB lid). LV CBs installed to a LV distribution board at a UKPN IFI trial site. Switches being installed to a link box in place of standard links.

  4. LV Remote Control & Automation - Smart LV Network Overview

  5. Project Scope & Key Objectives: Deployment Industrialisation & control integration Industrialise existing technology supplied for a small scale IFI project. Strategically populate 2 selected areas within the LPN LV network with the LV Remote Control & Automation devices (54 secondary substation sites). Integrate the LV remote control technology with our existing control platforms (via DNP3, and PLC) Actively manage the LV network to improve network performance. Use highly granular visibility of the LV network to improve our understanding and management of the LV network. Implement active network management tools. Evaluate and demonstrate the benefits of the technology over a 24 month trial/demonstration phase.

  6. LCNF Tier 1 - Project Location • Area 2 – City Rd B North West 1 & North West 4 feeders. • Area 1 – City Rd B South West Feeder Group. Trial will covers a total of 54 secondary substations supplying approximately 8400 customers.

  7. LCNF Tier 1 - Project Location & Scale (Area 1) • City Rd B South West feeder group; evaluate proactive management of the LV network. Area 1 – SW Feeder Group Secondary Substations • 65 link boxes to be populated with LV remote control devices. • 3 Feeder Group, with 38 distribution substations (27 to be populated). • Area is experiencing loading issues (inc load related fuse operations).

  8. LCNF Tier 1 - Project Location & Scale (Area 2) • City Rd B North West 1 & North West 4 feeders; evaluate benefits to network performance, offered by remote control and automated switching. Area 2 – NW 1 & 4 Feeders • 101 link boxes to be populated with LV remote control devices. • 25 distribution substations, covering area of approx 2km Sq. • Consistently worse feeders from CI/CML perspective.

  9. LV Network Visibility – Load Monitoring Smart Urban LV Network – Available Analogues Results from an early IFI Trial • 1 x RTU • 3 x CBs • Measurement samples over 30 minute intervals. • Voltage: Min, Max, Average • Current: Min, Max, Average • Real Power:Min, Max, Average • Reactive Power: Min, Max, Average • Power factor: Min, Max (i.e. closest/furthest from unity) • Average THD % • Voltage harmonics: Max % harmonics up to 50th harmonic (available on demand from direct request to RTU) D • Fully populated 4 way LB, NOP in quadrant C A NOP • 3 quadrants populated (9 switches installed ) as one quadrant leads to pot-end C B • 1 x RTU • 3 x CBs

  10. Key problems and solutions Smart LV Network Traditional LV Network • Reduce operating costs for fault response • Faster restoration of supply to customers • Improve reliability statistics LV Network Faults • Response and isolation can take a number of hours • Penalties incurred & high operational costs to resolve Remote Control • Feeder and network voltages • Load current and direction • Peak fault current and direction • Enables integration of distributed generation and EV LV Network Visibility • Feeder overloading due to EV, heatpumps, etc. • Voltage or harmonic issues due to renewable generation Load monitoring • Arc-less current switching • Fault sensing technology • Intelligent load make/ fault make technology • Phase-Phase voltage fault verification / alarms • Hazardous manual operations • Contact arcing • High fault currents • Damage to transformers & cables Safety Solid state switching

  11. Reliable communication to underground LB for control and load monitoring Power line carrier communications • Power line carrier reliability and performance critical especially during LV faults • Existing solutions for smart metering inadequate for LV network automation • Design of end to end communication layers above plc networking layer critical to success • G3 plc offers improved bandwidth and network formation • Higher bandwidth necessary for load monitoring • Lab test benches to simulate LV network environment • Validate performance during field trials

  12. Short circuit withstand High short circuit withstand requirements for densely populated urban LV Network • Silver tip contact welding or arcing due to blow-off forces • Load break switches utilise canted spring contact system with novel method for increasing contact force to reduce blow-off force • Canted springs increase the number of contact points and current paths • n multiple contacts create n (i/n) current paths and reduces forces by 1/n Blow apart Force FB = 4.45 x i2 x 10-7 (N) Ref: Electrical Contacts (Paul G. Slade)

  13. Current Voltage Load Make Compact switching technology Solid state switching technology • Thyristors gate drives are switched on just prior to zero crossing • Pulse peak current measured • Progressively increase pulse duration • Analyse peak currents • Determine if current is due to load or a fault Fault threshold levelswitch will not close Fault Make

  14. Usability Challenges & Solutions • Retrofit solution • Space constraints within link boxes • Optimising design to work with wide variety of installed LV switchgear • Safety and operator issues • Introduce safety features to prevent un-intentional operations • Regular design review meeting using rapid prototypes to address installation and safety issues • Improvements to remote control functionality and usability based on user feedback • Load monitoring • Optimisation of parameters monitored to match bandwidth available • Harmonic data storage and transfer separate from SCADA system

  15. Progress • Site selection and surveys complete. • Demonstration area preparation underway. • Next Gen PLC technology trialled and evaluated. • Tier 1 hardware industrialisation underway. • Approach to control integration (dynamic LB movement agreed) First 14 site deployment planned for Jun 2013

  16. Thank YouAny Questions? Contact Details Alexander Di Donato: alexander.didonato@ukpowernetworks.co.uk Technical Development Engineer Brendan Normoyle: bnormoyl@te.com TE Connectivity R&D Manager Matthieu Michel : matthieu.michel@ukpowernetworks.co.uk Technology Innovation & Co-ordination Manager

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