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

2. Improved safety Enhanced network modelling / planning 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. Maximise utilisation of plant Quality of Supply improvements Active Network Management

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

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

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

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

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

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

9. LV Network Visibility – Load Monitoring A B C D NOPNOP NOPNOP -1 x RTU -3 x CBs -1 x RTU -3 x CBs -Fully populated 4 way LB, NOP in quadrant C -3 quadrants populated (9 switches installed ) as one quadrant leads to pot-end Results from an early IFI Trial Smart Urban LV Network – Available Analogues 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)

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

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 F B = 4.45 x i 2 x 10 -7 (N) Ref: Electrical Contacts (Paul G. Slade) Blow apart Force F B = 4.45 x i 2 x 10 -7 (N) Ref: Electrical Contacts (Paul G. Slade)

13. Compact 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 Current Voltage Load Make Fault threshold level switch will not close Fault Make Solid state switching technology

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 You Any 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