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ukpowernetworks.co.uk
IFI / LCNF Report April 2012 – March 2013
For the licence companies:
UK Power Networks (LPN) plc
UK Power Networks (EPN) plc
UK Power Networks (SPN) plc
UK Power Networks (Operations) Limited. Registered in England and Wales. Registered No. 3870728. Registered Office: Newington House, 237 Southwark Bridge Road, London,
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Contents
Introduction ................................................................................................... 4
Background to the Innovation Funding Incentive ..................................... 6
Eligibility for IFI Funding .............................................................................. 6
New Projects over the Coming Year ........................................................... 7
Summary of Expenditure .............................................................................. 8
Highlights ..................................................................................................... 12
Strategy ........................................................................................................ 21
Managing Asset Risk and Improving Fault Performance ....................... 28
Automated Asset Registration (Completed) .................................................. 29
Vegetation Management (Completed) .......................................................... 31
Contact Voltage Testing (Completed) ........................................................... 33
National Underground Assets Group (NUAG) (Completed) ......................... 35
Tree Growth Regulator .................................................................................. 37
Overhead Line Incipient Fault Location ........................................................ 39
Earthing Information System ......................................................................... 41
Developing Long Term Asset Risk Replacement Modelling ......................... 43
Development of technologies to extend the life of Link boxes and mitigate the
impact of cable pit disruptive failures ............................................................ 45
Detection of Broken and Low Hanging Conductors ...................................... 48
Earthing Design Tool ..................................................................................... 50
Leveraging Industrial and Commercial Demand Response and
Dispatchable Generation ............................................................................ 52
Bankside Heat Transfer ................................................................................ 53
Automated LTDS Diagrams (Completed) ..................................................... 55
Managing Residential and Small and Medium Enterprise (SME)
Consumer Demand ..................................................................................... 57
Supergen 3 HiDEF Highly Distributed Energy Futures ................................. 58
Active Distribution networks with full integration of Demand and distributed
energy RESourceS (ADDRESS) (Completed) .............................................. 61
Home Based Flexible Demand Management (HBFDM) ............................... 63
New Options to Release Capacity at 11kV, 33kV and 132 kV ................. 65
Increased Capacity from Existing Overhead Line Routes ............................ 66
Urban Transformer Substation ...................................................................... 68
Strategic Technology Programme (STP) Module 2 – Overhead Networks .. 70
Strategic Technology Programme (STP) Module 5 – Networks for Distributed
Energy Resources ......................................................................................... 72
Transformer Design for FR3 (Completed) .................................................... 74
Fault Level Management Study .................................................................... 76
Understand Current and Future Performance of the HV and LV
Network ........................................................................................................ 78
Distribution Network Visibility ........................................................................ 79
LV Remote Control and Automation / Smart Urban LV Network .................. 82
Strategic Technology Programme (STP) Module 3 – Cable networks ......... 86
Strategic Technology Programme (STP) Module 4 – Substations ............... 88
High Performance Computing Technologies for Smart Distributed Network
Operation (HiPerDNO) (Completed) ............................................................. 90
Understand the Condition of Our Assets ................................................. 93
UK Power Networks (Operations) Limited. Registered in England and Wales. Registered No. 3870728. Registered Office: Newington House, 237 Southwark Bridge Road, London,
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Sustainable Asset Risk and Prioritisation Modelling ..................................... 94
Helicopter Mounted Partial Discharge Locator ............................................. 96
Develop Commercial Solutions and Products ......................................... 98
Smart Power Distribution .............................................................................. 99
Collaborative Programmes ...................................................................... 101
Energy Innovation Centre ........................................................................... 102
Power Networks Research Academy ......................................................... 105
Collaborative ENA R&D Programme .......................................................... 108
UK Power Networks (Operations) Limited. Registered in England and Wales. Registered No. 3870728. Registered Office: Newington House, 237 Southwark Bridge Road, London,
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Introduction UK Power Networks operates the three licensed electricity distribution networks serving London, the East of England and the South-East of England. These networks serve more than eight million homes and businesses and support critical national infrastructure. We are the lowest cost, most reliable and most innovative DNO group. Our obligations are to invest wisely and cost-effectively in infrastructure, offer timely and affordable connections to our network and maintain high standards of security of supply. In parallel, we have a core challenge to support the transition to a low-carbon economy. The UK Government’s Carbon Plan
1 outlines how the
Government proposes to manage the UK’s transition to a low carbon economy; it contains ambitious proposals for generating electricity from low carbon and renewable sources, and for electrification of heat and transport. Wide-scale adoption of electric vehicles (the batteries of which will be charged from the electricity distribution network) and electric heating (which will be supplied by the electricity distribution network) will be fundamental to achieving these targets. UK Power Networks’ challenge is to understand how future electricity demand will change, and to then develop new tools and design options to add to our armoury in order that this increased level of electricity demand can be met efficiently and economically. Innovation is central to this challenge. This annual report is our summary of innovation activities which have been funded by the Innovation Funding Incentive (IFI). We are aware that a number of other important stakeholders will be reading this report in order to understand our activities. For this reason, we provide some initial context by introducing the company, our approach to innovation and the background to the IFI. Our activities funded by the IFI form only part of our overall innovation portfolio. We have been awarded a total of £44m of funding from the Low Carbon Networks fund tier 2, the largest amongst the DNO groups. Throughout the report we refer to other innovation activities, including LCNF Tier 1 and Tier 2 projects. You can keep up to date with developments on our larger scale LCNF Tier 2 Smart Grid trials: ‘Smarter Network Storage’, ‘Low Carbon London’ and ‘Flexible Plug and Play’, through their regular progress reports published on the Ofgem website
2.
Further information relating to these projects can be found on the project’s dedicated website: www.ukpowernetworks.co.uk/internet/en/innovation/
Company Structure
UK Power Networks owns and operates the licensed electricity distribution networks serving the East of England, London and the South-East of England. The licensees managed by UK Power Networks are:
Eastern Power Networks plc for the East of England, referred to as ‘EPN’ in the rest of this report
London Power Networks plc for London, referred to as ‘LPN’ in the rest of this report
South Eastern Power Networks plc for the South East of England, referred to as ‘SPN’ in the rest of this report
These licence areas are shown in the map in Figure 1 overleaf.
1 http://www.decc.gov.uk/assets/decc/11/tackling-climate-change/carbon-plan/3702-the-carbon-plan-delivering-our-low-carbon-
future.pdf 2 http://www.ofgem.gov.uk/Networks/ElecDist/lcnf/stlcnp/Pages/stp.aspx
3 http://www.ofgem.gov.uk/Networks/ElecDist/lcnf/Pages/lcnf.aspx
2 http://www.ofgem.gov.uk/Networks/ElecDist/lcnf/stlcnp/Pages/stp.aspx
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Figure 1: The areas served by UK Power Networks
Innovation activities across the EPN, LPN and SPN licensed electricity distribution areas are conducted by UK Power Networks. For each project, we allocate expenditure across the three license areas in proportion to the major assets within those license areas that are expected to benefit from the innovation activity, or according to the number of customers in each licensed area who will benefit. For example, our innovation projects associated with overhead line networks are largely funded from the IFI allowance allocated to the EPN and SPN license areas, where the vast majority of our overhead line network is to be found. Our innovation activities typically fall into a number of categories: to understand a future issue and build a timeline for action; to inform engineering decisions; or to develop new solutions such as test equipment, sensors, devices which can make decisions and control the network, network management software and desktop design tools. UK Power Networks operates a balanced portfolio of innovation, with projects ranging from early-stage research through to trials on our network. Whilst the IFI has been a significant source of funding for our innovation activities, we seek to leverage other sources of funding where possible. In parallel with the activities reported here, UK Power Networks is strongly involved with Ofgem’s Low Carbon
SPN
LPN
EPN
UK Power Networks (Operations) Limited. Registered in England and Wales. Registered No. 3870728. Registered Office: Newington House, 237 Southwark Bridge Road, London,
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Network Fund (LCNF)3. As well as the LCNF Tier 2 projects, (Low Carbon London, Smarter Network
Storage, and Flexible Plug and Play), five smaller LCNF Tier 1 smart grid projects are also registered covering areas ranging from remote control of the Low Voltage (LV) network, greater network monitoring and the impact of photovoltaic (PV) generation; again, details of which can be found on the Ofgem website.
Background to the Innovation Funding Incentive The primary aim of the Innovation Funding Incentive (IFI) is to encourage both distribution and transmission network operators to apply innovation in the technical development of their networks. Ofgem recognises that innovation has a different risk/reward balance compared with a network operator’s core business. The incentives provided by the IFI mechanism are designed to create a risk/reward balance that is consistent with research, development, demonstration and deployment. IFI is intended to provide funding for projects primarily focused on the technical development of the networks in order to deliver value (e.g. financial, quality of supply, environmental, safety) to consumers.
The IFI activities described in this report are governed by Standard Licence Condition 46 and Charge Restriction Condition 10 in the Electricity Distribution Licence. Their requirements can be summarised as follows:
A network operator is allowed to spend up to 0.5% of its combined distribution network revenue or its combined transmission network revenue, as the case maybe, on eligible IFI projects
Internal expenditure incurred by the network operator in running and implementing IFI projects can be considered as part of the total IFI expenditure accrued by the network operator
The network operator is allowed to recover 80% of its eligible project expenditure via the IFI mechanism within the network operator’s licence
Ofgem does not approve IFI projects, but network operators have to openly report their IFI activities on an annual basis
Ofgem reserves the right to audit IFI activities if this is judged to be necessary in the interests of customers
In April 2015, both the Innovation Funding Incentive and Low Carbon Networks Fund (Tier 1) will be replaced by the Network Innovation Allowance. UK Power Networks has requested via the RIIO-ED1 process an allowance of 0.5% of revenues to continue work similar to that reported, and will continue to participate in the competitive funding rounds under the Network Innovation Competition.
Eligibility for IFI Funding Projects will be judged as eligible within the IFI, provided that:
The project satisfies the eligibility criteria described in Engineering Recommendation G85, Issue 2, ‘Innovation Good Practice Guide for Energy Networks’, published by the Energy Networks Association (ENA)
The project has been well managed as defined in Engineering Recommendation G85; and
The reporting requirements have been met This report fulfils our reporting requirements for the regulatory year 2012/13 and demonstrates that our projects are being well managed. Each individual project report presented later in this report includes a project ‘score’ which summarises how the project meets the eligibility criteria laid down in Engineering Recommendation G85. Work that has been approved within an industry recognised or national/governmental programme (such as a Technology Strategy Board Programme or European Commission Programme) and whose
3 http://www.ofgem.gov.uk/Networks/ElecDist/lcnf/Pages/lcnf.aspx
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terms of reference clearly address innovation in the networks may be considered eligible within IFI if it meets the defined criteria. Co-operation between network operators and other organisations to pursue IFI projects is encouraged. In such cases the overall project would be expected to meet the IFI eligibility criteria and it would be acceptable for each participating network operator to use the eligibility case for the overall project. IFI projects that secure additional funding from outside agencies, such as the Technology Strategy Board or the European Commission, will not trigger any claw-back of IFI funding by Ofgem. Engagement with industry engineering committees is not considered eligible as this does not constitute a project with a specific target or delivery. In the event that a network operator provides resources to contribute to an eligible IFI project which is led or managed by a third party, those costs incurred by the network operator, that are not recovered from the third party, will be considered to be eligible IFI expenditure. Where supporting such projects with a net cost to the network operator, the network operator should demonstrate that the expected benefits to the network operator exceed the costs involved. IFI projects, by their nature, involve risk. It is understood, therefore, that not all IFI projects will meet their aims and objectives and deliver net benefits. However, it is expected that the benefits from those that do succeed will significantly outweigh those which do not, and exceed the overall costs of a network operator’s IFI programme.
New Projects over the Coming Year You can read about new projects as they are added on the Energy Networks Association (ENA) Smarter Network Portal (http://www.ena-eng.org/smarter-networks/). The portal (Figure 2) allows users to search our project portfolio, and those of other DNOs, for topics of interest.
Figure 2: Smarter Network Portal
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Summary of Expenditure Figure 3 and Tables 1 and 2 below show UK Power Networks’ usage of the innovation funding incentive since its inception:
Figure 3: Trend of innovation spend
Regulatory Year Total IFI Expenditure IFI Allowance
This regulatory year 12/13 £3,053.8k £6,260.0k
Regulatory year 11/12 £2,668.9k £5,392.3k
Regulatory year 10/11 £3,339.5k £4,793.3k
Regulatory year 09/10 £3,545.2k £4,460.6k
Regulatory year 08/09 £3,922.6k £4,425.5k
Regulatory year 07/08 £4,993.5k £4,326.3k
Regulatory year 06/07 £3,575.8k £3,938.3k
Regulatory year 05/06 £2,570.9k £3,664.7k
Early start report 04/05 £275.8k N/A
Total £27,946.0k £37,261.0k
Table 1: IFI expenditure and allowance
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Details of the expenditure in the current regulatory year are shown below:
EPN LPN SPN TOTAL
IFI carry forward from 11/12 (£k) £981.7k £894.5k £692.8k £2,569k
Combined distribution network revenue (£m)
£509.9m £404.5m £337.6m £1,252m
Allowance 12/13 (Including carry forward) (£k)
£3,531.2k £2,917.0k £2,380.8k £8,829.1k
Eligible IFI expenditure 12/13(£k) £1,160.2k £1,218.0k £675.6k £3,053.8k
Of which internal expenditure 12/13(£k)
£144.1k £113.1k £81.5k £338.7k
The IFI carry forward to 13/14 (£k) £1,274.7k £804.5k £844.0k £2,923.2k
Table 2: IFI spend/allowance/carry forward per licence area
Expenditure from IFI Projects
Table 3 below details individual project expenditures from April 2012 to March 2013. Investment is apportioned across UK Power Networks’ three licence areas according to the number of customers, or assets in each area most likely to benefit from the research outcomes. The basis of the allocation is specified in each project report.
EPN LPN SPN Total
Managing Asset Risk and Improving Fault Performance
Automated Asset Registration (Completed)
No expenditure for 2012/13 £0
Vegetation Management (Completed)
No expenditure for 2012/13 £0
Contact Voltage Testing (Completed)
£0 £394,676 £0 £394,676
National Underground Assets Group (Completed)
No expenditure for 2012/13 £0
Tree Growth Regulator £1,222 £1 £436 £1,659
Overhead Line Incipient Fault Detection
£97,808 £46 £34,914 £132,768
Earthing Information System £38,437 £24,640 £24,404 £87,481
Developing long term asset risk replacement modelling
£25,767 £14,208 £16,342 £56,317
Development of technologies to extend the life of link boxes and mitigate the impact of cable pit disruptive failures
£38,251 £155,747 £30,338 £224,336
Detection of broken or low hanging conductors
£33,081 £15 £11,808 £44,904
Earthing Design Tool £28,361 £18,180 £18,007 £64,548
Leveraging Industrial and Commercial Demand Response and Dispatchable Generation
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Bankside Heat Transfer £0 £0 £0 £0
Automated LTDS diagrams (Completed)
£48,317 £30,973 £30,678 £109,968
Managing Residential and Small and Medium-Sized Enterprise (SME) Consumer Demand
Supergen 3 – HiDef Highly Distributed Energy Futures
£9,600 £6,154 £6,095 £21,849
Active Distribution networks with full integration of Demand and distributed energy RESourseS (ADDRESS) – please see note at foot of table (Completed)
No expenditure for 2012/13 £0
Home Based Flexible Demand £4,798 £3,076 £3,047 £10,921
New Options to Release Capacity at 11kV, 33kV and 132kV
Increased Capacity from Existing Overhead Line Routes
£137,580 £65 £49,111 £186,756
Urban Transformer Substation £1,124 £620 £713 £2,457
STP Module 2: Overhead Networks £28,352 £18,175 £18,002 £64,529
STP Module 5: Networks for Distributed Energy Resources
£22,665 £14,530 £14,391 £51,586
Transformer Design for FR3 (Completed)
No expenditure for 2012/13 £0
Fault Level Management Study £0 £4,874 £0 £4,874
Understand Current and Future Performance of the 11kV and LV Network
Distribution Network Visibility £0 £143,786 £0 £143,786
LV Remote Control and Automation £430,276 £245,166 £281,041 £956,483
STP Module 3: Cable Networks £34,354 £22,023 £21,813 £78,190
STP Module 4: Substations £24,758 £15,871 £15,720 £56,350
High Performance Computing Technologies for Smart Distributed Network Operation (HiPerDNO) (Completed)
£127 £81 £80 £288
Understand the Condition of our Assets
Sustainable Asset Risk and Prioritisation Modelling
£79,344 £43,751 £50,321 £173,416
Helicopter Mounted Partial Discharge Locator
£340 £118 £270 £728
Develop Commercial Solutions and Products
Smart Power Distribution £0 £12,717 £0 £12,717
Collaborative Programmes
Energy Innovation Centre £37,547 £24,070 £23,840 £85,457
Power Networks Research £17,665 £11,324 £11,216 £40,205
UK Power Networks (Operations) Limited. Registered in England and Wales. Registered No. 3870728. Registered Office: Newington House, 237 Southwark Bridge Road, London,
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Academy
Collaborative ENA R&D Programme
£20,463 £13,118 £12,992 £46,573
TOTAL £1,160,237 £1,218,005 £675,579 £3,053,822
Table 3: Allocation of expenditure per project and licence area
Please note that for readability, all the figures in the report have been rounded to the nearest £ or £k as appropriate.
The next section presents the highlights from our innovation programme, and some of the key
projects carried out under the Innovation Funding Incentive, the Low Carbon Network Fund and the
Energy Technologies Institute.
Portfolio highlights
Our IFI and LCNF projects have again delivered a number of successful outcomes. The next few
pages show innovations which:
Enable network and other data to be easily combined, visualised and analysed
Have demonstrated a new technology for remote control of the low-voltage (LV) network and which is currently manually operated
Simplify complex site-specific and safety-critical calculations, to speed up design and quoting (earthing design tool)
Have made a multi-million pound saving on 33kV and 132kV overhead line circuit upgrades
We are also happy to demonstrate that we are leveraging other sources of funding. Our work with the
Energy Technologies Institute culminated in the commissioning of a Fault Current Limiter in May
2013.
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Highlights
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Distribution Network Visibility (DNV)
The project has developed visualisation software that will allow UK Power Networks to evaluate the
benefits that can be derived from improved use of existing Remote Terminal Units (RTUs), better
visualisation of available data, and enhanced monitoring of the distribution network.
Case Study – Overloaded Transformer Replacement Deferral
A transformer rated at 500kVA located at a secondary substation
in Bromley High Street had been referred to the distribution
planning team for upgrade to a higher rated one. Maximum
Demand Indicator (MDI) readings taken at site over the years
suggested that the transformer was overloaded and should be
replaced.
Analysis:
The DNV application, developed as part of the project, provides the load history of the transformer for
the past two years suggesting very little time had been spent above 500 kVA and the transformer
does not need immediate replacement. The data used in the analysis below is the load (kVA) data
collected from the RTU at site which is measuring current and voltage at the LV tails of the
transformer.
Figure 4 below shows half hourly average kVA for past two years indicating a typical winter peak
demand. Figure 5 shows the average daily kVA for December 2012 illustrating the available capacity
during the day.
Figure 4: Loading in kVA plotted over 2011 to
2013
Figure 5: Average daily load profile over December
2012
The Load Duration curve for the past five years also showed that the percentage of time the
transformer has been over 100% utilised is very small and the transformer has never been above
120% utilisation.
Conclusions:
From the analysis above it is suspected that the MDI readings are incorrect and distribution planning
will not require the replacement of the transformer. This decision will be taken once load readings
have been taken at site and are seen to agree with the readings that the RTU is reporting for the
same time period.
Transformer MDI Readings
2006 300 kVA
2007 576 kVA
2009 792 kVA
2011 756 kVA
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Business Benefits
Being able to quickly assess the historic transformer utilisation enables the business to confirm MDI
readings and correctly identify transformers needing replacement. The analytical tools enable the
time of day of maximum demand and the average daily load profile to be visualised as well as the
load duration curve to enable an assessment of the effect of load growth and the connection of new
load. Deferring a secondary substation transformer replacement by five years has an equivalent value
benefit in today’s terms of £50k.
Other visualisations and capabilities
In addition to the visualisations shown above, the DNV application also allows the user the ability to carry out investigations via the GIS and Network Report functionalities as seen in Figures 6 to 9.
Load profiles:
Advanced Network Analytics (Reports)
Figure 6: GIS functionality showing secondary
substation load profiles, red indicating industrial
load, yellow commercial load and blue residential
load
Three phase visualisations:
Figure 7: Network wide report functionality with the
ability to run reports based on a number of
parameters
Planner tool:
Figure 8: Three Phase Pin functionality for viewing
3 phase monitoring data simultaneously on a GIS
map
Figure 9: A network planner’s tool for quickly
viewing multiple HV feeders loading over a chosen
time period
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Smart Urban Low Voltage Network
In order to facilitate smarter management and use of the LV network, UK Power Networks and TE
Connectivity have collaborated as part of an IFI project. This resulted in the development of a new
solid-state switching technology for use on the LV distribution network, in the form of retrofit, remotely
controllable, FM/FB (fault make/fault break) circuit breakers and FM/LB (fault make/load break)
switches.
The prototype devices developed during the IFI project have been installed for approximately 12
months, and key functionality expected to deliver benefits in the planned large scale LCNF Tier 1
demonstration of the technology (such as transient fault identification and remote network
reconfiguration) have been successfully evaluated.
Case Study – Remote Network Reconfiguration & Load Transfer
Remote network reconfiguration to transfer load from one substation to another has been
demonstrated and verified by the half-hourly load monitoring data collected prior to and after the
network reconfiguration.
Figure 10 shows the IFI trial network running as normally configured.
Daily load profile, link box 61552 (Way 2) IFI trial network (normal running arrangement)
Figure 10: Average daily load profile at link box 61552 (way 2), and IFI trial network diagram (normal
running arrangement)
The circuits in highlighted in pink are fed from substation 61552, and the blue highlighted circuits are
fed from substation 60663.
The substations supply three link boxes (underground electrical junction boxes) on the LV circuit
between them, and all circuits from both substations are configured in a radial running arrangement,
in that they are not directly connected to a circuit from another substation.
A normally open point at Link Box 610699 maintains the radial running of the LV circuit between the
two trial substations.
By remotely moving a normally open point between the two trial substations, LV Control Engineers
have been able to demonstrate the transfer of load from one substation onto another (see Figure 11).
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Daily load profile, link box 61552 (Way 2) IFI trial network (reconfigured)
Figure 11: Average daily load profile at link box 61552 (way 2), and IFI trial network diagram (remotely
reconfigured running arrangement)
In the reconfigured network, substation 61552 is supplying a greater proportion of the LV circuit
between the two substations and therefore sees a corresponding increase in load.
Figure 12 shows the average daily current
through LV way 2 at substation 61552 over
a four week period.
The normally open point was remotely
moved on 9 May, and the transfer of load
can be clearly seen.
A corresponding drop in load at substation
60663 was also observed.
Figure 12: daily average current at 61552 (network reconfiguration on 9 May 2013)
Business Benefits
The ability to remotely or dynamically (based on network condition) reconfigure and monitor the LV
network will enable:
Existing LV plant to be utilised more effectively
High loading issues to be addressed if transfer of load is possible
Improvements in quality of supply performance
A reduction network losses
LV network reinforcement to be better targeted or deferred
REMOTE NETWORK
RECONFIGURATION
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Substation Earthing Design Tool
An Excel based earthing design tool has been developed, and is now actively being used by
connections designers and distribution planning engineers to ensure a much higher degree of
accuracy at optimal cost for secondary distribution (11kV/400V) substations.
Figure 13: Substation earthing design tool
The unique feature of the tool is that it brings all the relevant data together and allows the user to optimise the design interactively. The data available or used by the tool includes:
Source substation earth resistance, fault current, earth potential rise (EPR) and protection
settings (from various UK Power Networks data sources)
Specially designed standard substation earthing arrangements, for which technical parameters
are calculated depending on the soil parameters
Detailed underground cable and overhead line electrical parameters (that include sheath return
impedance and mutual coupling)
Earth contribution from the locally connected network and its cables
Safety limits
The user selects the source substation (from a drop-down list), enters details of the connection to the
new secondary substation (underground cable/overhead line lengths/types), selects the soil resistivity
and the standard earthing arrangement applicable to the new substation. The design tool then
provides the following:
Site specific earth fault current
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Protection clearance time
Earth resistance for new substation
EPR at the new substation resulting from a local fault
Transfer voltage (from the source substation)
Touch and step voltages and how they compare to acceptable limit values
HOT/COLD4 site classification
The user then has an opportunity to optimise the design by altering parameters such as earth rod
length and horizontal electrode used. A form is automatically produced with the design and
construction information needed by the delivery teams.
The first version of the tool is already being used by designers and planning engineers however
refinements are to be added over a six month period to improve the user experience. Use of the
design tool has already highlighted the major contribution of the wider connected legacy cable
network and a previous lack of understanding about its practical application to the reduction in earth
resistance seen at the substation.
Business Benefits
The new design tool brings together the data and complex calculation techniques that allow robust
earthing systems to be designed quickly, increasing safety at secondary substations.
Users are already becoming much more knowledgeable about earthing and are now able to consider
more advanced situations that are related to load growth or network reconfiguration. This will lead to
better and safer designs as UK Power Networks moves away from the coarse assumptions relied
upon previously.
4 If the earth potential rise is greater than 430V the Secondary substation is designated HOT. The HV and LV earths have to be segregated at a HOT and there are also implications for telecoms equipment and operators.
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Increased Capacity of Overhead Lines
UK Power Networks has been involved in several innovation projects relating to overhead lines
(OHLs) over DPCR4 and DPCR5. Most of these have been collaborative projects that have been
carried out in conjunction with some or all of the other DNOs.
A project has been initiated to update our processes, provide useful guides to inform our staff and to
implement new techniques. Reviewing various methodologies we found that time-variable ratings
(Day/Night or Four Season) do not deliver sufficient benefit to be worthwhile implementing.
Investigating demand management for outage scenarios showed promise but requires an
improvement in our data systems to make economic sense. This will be reviewed again in RIIO-ED1
once the data systems have been improved.
Looking to maximise capacity with existing lines and structures, Light Detection And Ranging (LiDAR)
scanning was used to prove existing clearances and to determine mitigating actions required (if any)
were a line capacity to be increased.
As more current flows
through an overhead
conductor the temperature
increases, causing it to
“sag” as the metal
expands thereby reducing
ground clearances.
On the trial routes (Pelham
/ Wymondley 132kV,
Sundon / Leighton
Buzzard 33kV) this
technology also identified
existing clearance
violations (when the line
would be operating at
maximum temperature)
that had been missed in
our regular patrols. These
were immediately actioned
for resolution.
Figure 14: OHL route
Business Benefits
This technology determined that with relatively few mitigating actions, capacity could be increased on
the two routes investigated. This has enabled the Pelham / Wymondley reinforcement, a £6.36 million
scheme to increase capacity by re-conductoring a route, to be deferred from 2014/15 until the
conductor condition requires its replacement.
Temperature monitoring is also being installed to ensure that the maximum operating temperature is
not exceeded, in order to prevent damage to the conductor. This would only occur under two co-
incident faults or a single fault during a maintenance outage – assuming that this is under peak load
conditions. This approach is being rolled out across the schemes proposed for re-conductoring in
RIIO-ED1 to determine whether any of this work can be deferred. This includes the use of Light
Detection and Ranging (LiDAR) and temperature monitoring of OHLs as a means of assessing
condition problems.
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11kV Fault Current Limiter (Energy Technologies Institute)
UK Power Networks is keen where possible to leverage additional sources of funding and to be
involved in collaborative projects. To that end, UK Power Networks is working with the Energy
Technologies Institute (ETI) on a project to reduce the impact of faults on electricity distribution
networks.
This project involves the development and trial of a revolutionary new fault current limiter (FCL) at a
UK Power Networks’ main substation in Newhaven, East Sussex. This FCL has been
comprehensively tested by a certified high power laboratory in Australia, where it underwent more
than 50 fault tests, before being shipped to the UK. The FCL is now in service on the 11kV
distribution network and it will be demonstrated in operation for two years.
UK Power Networks has fully approved the design and testing, and for the purposes of the
demonstration, is acting as network operation customer. E.ON’s New Build & Technology division is
providing technical assurance expertise and network modelling support.
Developed and manufactured by Israel-based GridON with its Australian partner the Wilson
Transformer Company, this innovative state-of-the-art FCL enables the cost-effective growth and
increased flexibility of electricity distribution systems.
The design is based on combining industry-standard, proven transformer technology with GridON’s
unique and proprietary concept of magnetic flux alteration to saturate the iron core. GridON’s device
offers performance benefits including instant, self-triggering response to a fault, immediate recovery
following clearance of the fault without
network interruption, and suppression of
multiple consecutive faults. It is the first
such fully tested, commercially viable non
superconducting pre-saturated fault
current limiter.
Business Benefits
Removing the fault level constraints
without costly network upgrades enables
the installation of more low carbon and
other electricity generation directly onto
the distribution system, with shorter
connection times and reduced connection
costs. It also enables smart distribution
networks with increased network
efficiency, flexibility, reliability and
resilience. The breakthrough in design
removes the need for superconducting
components which results in a simple,
reliable and low maintenance solution. It is
fully scalable for use at all voltage levels
on both distribution and transmission
systems. This will potentially help minimise
the costs of upgrading the UK’s electricity
distribution and transmission networks
over the next 20 to 30 years.
The Fault current limiter has now been commissioned and is fully operational.
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Strategy
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Our guiding principles
Innovation has many different definitions and interpretations depending of the context in which it is
used. UK Power Networks views innovation as introducing something new to our business processes
or distribution network so we can provide a better, cheaper or quicker service than before. Innovation
does not always have to be ground-breaking; many improvements are achieved by smaller step-by-
step improvements.
In UK Power Networks we often think of innovation as either:
Incremental innovation: continuous evaluation to achieve gradual improvements of our business
efficiency, for example by using small remote controlled helicopters to carry out overhead line
inspections
Disruptive or transformational innovation: redefining the way we run our business or network,
embodied in our Low Carbon Network Fund (LCNF) projects to trial Smart Grid technologies
Why Do We Innovate?
In UK Power Networks we innovate to identify opportunities for developing new or more efficient
services, processes or solutions. This rationale for innovation contains two vital elements which are
at the heart of our approach to innovation:
Value to our stakeholders – if we cannot identify how a proposed innovation will deliver value to
our stakeholders then we do not proceed with it. We are clear of our duties to serve customers;
support the economic recovery; and facilitate the government’s carbon reduction targets. Our
innovations deliver across all of these goals
Continuous improvement – we are committed to deliver continuous improvement of our services,
processes and solutions. This commitment covers the entirety of UK Power Networks, including
customer relations, new connections, management of our substation assets, the remote
workforce, health, safety and sustainability, our construction programme and back office
functions, rather than being focused only on specific areas
How Do We Innovate?
We undertake innovation by a variety of approaches that are tailored to achieving effective outcomes
and value for money. Our innovation projects draw on internal and external resources so that we take
advantage of best advice and experience, we adopt the best techniques, and we build new in-house
knowledge for the future. This leads us to work with large and small manufacturers, academia,
specialist advisers, community organisations and other stakeholder representatives.
In order to deliver innovation of the scale that we believe is required, we access funding from a variety
of sources over and above our own financial support. We will naturally seek to optimise our use of
available income from the IFI, LCNF, NIA, NIC or third party funding agencies. As we identify new
innovation ideas, they are scoped out to the extent that is required in order to understand the
associated costs, benefits and risks. We then evaluate if the potential project will deliver appropriate
new value on a self-funding basis and decide whether or not to proceed. Where the benefits are not
immediately quantifiable or available, but could be substantial, we will seek to deliver the project using
the other available innovation funding mechanisms.
There will also be circumstances where we identify technology development activities which we
regard as worthwhile but may not be eligible for funding; in these scenarios we will determine on a
case-by-case basis if the potential value is sufficiently high for us to self-fund. An example of this was
the Green Rhino filtration bag, which was developed with a manufacturer and offers a means to
remove water from an excavation, by ensuring that any contaminants are held in the bag and
disposed of whilst the remaining water is released.
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We actively engage in the ENA Research and Development (R&D) working group and we collaborate
with other DNOs on specific projects. Participating in collaborative projects is a good way of delivering
value for money for customers, sharing information and results across our industry.
Those innovation activities or projects that are selected for delivery are actively monitored to clearly
identify the business case for innovation throughout their delivery lifecycle. This will help us ensure
that the expected value to be delivered remains on target, and enables us to monitor its realisation
after delivery. This is formalised in a set of ‘stage gates’ including an after-the-event post investment
appraisal, in line with project management best practice.
The Future Networks Team is responsible for maintaining balance within the overall portfolio of
innovation projects. Our balanced portfolio contains a mix of:
Projects addressing short, medium and long term issues from across our innovation themes;
Projects that are high and low risk
Projects to inform decision making or that are a step further and are likely to result in practical
changes to our internal engineering policies
Projects that are yet further developed and are trialling full-scale new technology solutions (e.g.
LCNF Tier 2 projects)
Projects which are addressing both technical and commercial challenges
Projects being funded collaboratively and those which are contracted directly to UK Power
Networks
Projects that involve external partners and suppliers, so that the portfolio is neither too diverse in
its relationships nor too dependent on a few critical relationships.
How Do We Make Innovations Business As Usual?
Our innovation projects will only be successful if we embed the new knowledge into our ‘Business as
Usual’ (BaU) practices to improve the way we work and serve our customers.
The integration of innovation sponsors at a senior level within the directorates in the company is an
important part of this process. Their senior roles allow them to be fully aware of the working practices
and day-to-day challenges; therefore, they are best placed to drive the company through change.
We have developed a systematic approach that is being integrated into our company policies and
procedures. This includes management oversight through project sponsorship and tracking
mechanisms to ensure closed-loop governance. These governance mechanisms ensure that network
innovation project outputs are consistently embedded into BaU solutions and become part of our
toolkit for planning and operational activities at all stages in the asset life cycle.
An important requirement at this stage is to adopt the knowledge and skills to deliver the outcomes of
demonstration projects and make solutions suitable for deployment at scale. To assist the transition to
BaU for our network innovation we have developed and implemented an approach we call the Smart
Network Plan (SNP). The SNP is a comprehensive transitioning plan and governance process which
gives confidence that the outputs of network innovation projects are migrated smoothly into BaU
solution options that can be adopted at scale throughout the RIIO-ED1 period and beyond.
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Capability Themes Areas
Figure 15 below shows the seven themes into which we organise our innovation activities. These
themes describe the actions that need to be carried out to deliver innovation in a cost effective and
timely manner.
Figure 15: UK Power Networks’ innovation themes
The five themes at the centre of the diagram (labelled 1-5) are critical success factors in the service that we offer to current and potential customers. The two themes shown in the outer ring (labelled 6 and 7) describe a more interactive relationship with our customers, whether directly or through energy suppliers, aggregators and other market entities. 1 Managing asset risk and improving fault performance At the centre of the diagram is the most basic innovation theme. This will correspond to all activities or innovation which we need to carry out in order to fulfil our central function of serving existing customers and managing risks to our electrical assets. Examples of innovation that falls into this category are investigations into improved fault restoration techniques and methods which have the potential to improve reliability of customer supply. 2 Understand current and future performance of the 11kV and LV network The change in demand and the introduction of micro-generation will bring new pressures to the parts of our network which are currently least visible to us in real-time. This includes changes to the Low Voltage (LV) network and 11kV (or in some cases 6.6kV) feeders and the load cycle on our assets. It is important to understand, for example, their ability to dissipate heat and thereby cool down between peaks of high load. Understanding of the loading on the network is essential to the service improvements that we are seeking to make in time-to-connect and cost of connection.
Managing
asset risk and
improving fault
performance5
4
3
2
1
7
6
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3 New options to release capacity at 11kV, 33kV and 132kV This theme is strongly targeted to facilitate the low carbon economy. We are currently exploring the particular cases in which a commercial solution such as DSR may provide a way to avoid reinforcing the network. We are aware that the driver for these solutions is the greatly increased demand peaks which we might see as a result of the low carbon uptake. There are immediate applications for DSR, such as managing the load transfers that are required to support a wider 132kV reinforcement scheme; but our research intensity is based on the wider challenges arising as a result of the low carbon economy. Similarly, we are exploring the use of dynamic line rating technologies as a means of releasing network capacity. 4 Develop commercial solutions and products The alternatives that are explored throughout our innovation strategy are analysed in order to be implemented and therefore contracted. Therefore, in line with identifying the new options to release capacity at 11kV, 33kV and 132kV with our existing assets, it is critical to understand the commercial implications of the new technologies. This implies having a specific innovation theme related to developing commercial solutions and products to support the technological solutions. 5 Understand the condition of our assets Just as understanding the current and future performance of the 11kV and LV network, it is important for UK Power Networks to understand the condition of our assets. This will be essential to meet the efficiency savings that we have set for ourselves on our existing inspection and maintenance expenditure and asset replacement expenditure. 6 Leveraging I&C demand response and dispatchable generation The theme ‘Leveraging I&C demand response and dispatchable generation’ expresses a series of actions which UK Power Networks needs to take and capabilities which it needs to develop, in order to capitalise on the opportunities offered by Industrial & Commercial (I&C) demand and generation. Historically, the distribution network has been a passive network with a one-way power-flow towards end customers. This model will continue to change into a two-way network through the widespread adoption of DG, back-up generation, and Combined Heat and Power (CHP) schemes. A significant number of our I&C customers firmly view the distribution network as a two-way network in which they can make use of latent back-up generation capacity in the system reserve market. This capability could equally be deployed by the DNO to support the network in critical periods. Our outlook, customer interactions and back-office systems need to adapt to this and capitalise on it. 7 Managing residential and Small and Medium-sized Enterprise (SME) consumer demand The theme ‘Managing residential and SME consumer demand’ recognises the unprecedented opportunity represented by the roll-out of half-hourly smart meters to every residential and SME premises. Currently a proportion of the population have their electric home heating controlled or timed by Radio Teleswitch Service (RTS) technology. Smart meters will provide the opportunity to expand this small set of directly controlled customers and to introduce tariff-based incentives or additional offers which are more visible and immediate to the consumer.
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Possible future
Present
Distribution Network Operator (DNO)
Non-flexible demand Non-controllable distributed generation (DG)
Distribution System Operator (DSO)
Technical Aggregation
Flexible demand
EV
s
He
at
Co
olin
g
Wh
ite
g
oo
ds
Sto
rag
e
Dispatchable resources
Ne
two
rk
sto
rag
e
DG
co
ntr
acts
De
man
d
resp
onse
Non-regulated
An
cilla
ry s
erv
ice
s
En
ab
lin
g
infr
astr
uctu
re
Co
mm
erc
ial
ag
gre
ga
tio
n
Transition to a Distribution System Operator We strongly believe that the challenges we face require a radical change from the current business, and to a future in which DNOs become ‘Distribution System Operators (DSOs)’. This change is being strongly debated by government and the industry. It is clear that the DSO future defines a direction of travel for the DNOs which will take many years to navigate and with a great deal of uncertainty regarding timing, technologies and customer behaviour. The move from the present DNO to the possible future DSO, which innovation will play a key role in, is illustrated below.
What is a Distribution System Operator?
A Distribution Network Operator (DNO) continues to build in response to growth in maximum or peak demand. A DNO does not have the ability or desire to influence demand and generation, and tends to introduce flexibility only to the extent that it supports existing regulatory priorities (such as to reduce supply interruptions and the risk of catastrophic asset failure).
By contrast, a Distribution System Operator (DSO) has access to a portfolio of responsive demand, storage and controllable generation assets that can be used to actively contribute to both distribution network and wider system operation. A DSO builds and operates a flexible network with the ability to control load flows on its network. The combination of a highly flexible network and access to demand and generation response allows the DSO to contribute to the increasing challenge of encouraging demand to follow generation.
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Individual Project Reports
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Managing Asset Risk and Improving Fault Performance
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Automated Asset Registration (Completed)
Description of Project
Investigation into the use of Radio-frequency identification (RFID) technology in order to improve and automate various aspects of the asset-registration process.
Expenditure for
Financial Year
EPN LPN SPN
External £0 £0 £0
Internal £0 £0 £0
Total £0 £0 £0
The costs have been allocated in proportion to the total circuit length in
each licence area.
Expenditure in Previous
(IFI) Financial Years
External £29,652
Internal £2,682
Total £32,334
Expenditure in Previous
(IFI) Financial Years
This project has now closed and no further expenditure has been
incurred.
Total Project Costs
(Collaborative +
External + UK Power
Networks)
£32,334
Projected 2013/14
costs for UK Power
Networks
Project Completed
Technological Area and
/ or Issue Addressed by
Project
The first phase of this project explored technologies to support asset
registration and tracking to improve the visibility and management of
assets. Current processes can lead to inadequate visibility of assets for
short periods of time, causing issues and delays in the event of recalls
or faults.
Type(s) of Innovation
Involved
Technological
substitution
from different
application
Project
Benefits
Rating
Project
Residual Risk
Overall Project
Score
15 -4 19
Expected Benefits of
Project
Benefits, if automated asset registration were adopted, would include:
Improved productivity and efficiency of logistics staff and reduced
data entry
Improved investment decisions facilitated by better data
Definition of information standards and asset data requirements for
network operators
Easier identification of all affected assets in stock in the event of
equipment defects
Reduced need for data entry on commissioning assets, leading to
improved efficiency and reduced staff-time on site
Expected Timescale to
Adoption 2014/15
Duration of benefit
once achieved 10-15 Years
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Probability of Success 30%
Project NPV (Present
Benefits – Present
Costs) x Probability of
Success
£48,000
Potential for Achieving
Expected Benefits
Whilst the RFID technology performed well in the operational tests, the
investments required to integrate the use of tracking technology into
the existing processes are expected to be relatively high, and may
impact the feasibility of implementing the technology.
Project Progress
March 2013
No further developments were carried out in the past 12 months.
Recommendations for alternative and lower-cost improvements to the
registration process were made as a starting point for the development
of more advanced asset-tracking capabilities. Some outputs of the
research have been incorporated into the development of a ‘Small
Assets Data Solution’.
UK Power Networks will consider whether to implement an automated
registration solution as part of an on-going business transformation
programme.
Collaborative Partners N/A
R&D Provider Tata Consultancy Services
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Vegetation Management (Completed)
Description of Project
This project’s overall goal was to provide an improved understanding of
vegetation growth, and the way in which it encroaches on the safety
space around electrical equipment, known as the utility space.
This project is monitoring vegetation growth at 1,300 sites across the
UK and integrating the national database of vegetation growth into
existing vegetation management systems to promote an efficient,
spatially and climatically sensitive management of vegetation.
Expenditure for
Financial Year
EPN LPN SPN
External £0 £0 £0
Internal £0 £0 £0
Total £0 £0 £0
The costs have been allocated in proportion to the length of overhead
lines in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £400,218
Internal £36,859
Total £437,077
Total Project Costs
(Collaborative + External
+ UK Power Networks)
£1,740,000 Projected 2013/14 costs for
UK Power Networks Project Completed
Technological Area and
/ or Issue Addressed by
Project
Arboriculture
Rate of vegetation growth
Type(s) of Innovation
Involved Significant
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
17.8 1 16.8
Expected Benefits of
Project
The expected benefits include an integration of results into existing
vegetation management processes. This will enable UK Power
Networks and other collaborating DNOs to determine cutting patterns
and cycle lengths based on potential risks, allowing multiple savings to
be made.
Expected Timescale to
Adoption Year 2012
Duration of benefit once
achieved 20 Years
Probability of Success 70%
Project NPV (Present
Benefits – Present Costs) x
Probability of Success
>£4,000,000
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Potential for Achieving
Expected Benefits
A final report has been submitted to the project partners and the project
is complete.
Project Progress
March 2013
This project is now complete and the final report and associated
deliverables have been provided to project partners.
UK Power Networks is currently investigating ways in which the
knowledge and tools generated by this project can be integrated into the
business to improve the efficiency of tree cutting.
Collaborative Partners Electricity North West, Scottish Power Energy Networks, Western
Power Distribution, National Grid
R&D Provider ADAS
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Contact Voltage Testing (Completed)
Description of Project
Technical and practical evaluation of a surveying system, previously used in the United States, to detect the presence of voltages on metallic street furniture and DNO apparatus installed in the public highway. The aim of this project is to prevent members of the public being exposed to electrical voltages that have the potential to cause them harm. An evaluation of the system’s potential to provide an innovative and cost effective method for determining the condition of buried underground cable and associated plant, including the identification of any defects present, will also be undertaken.
Expenditure for
Financial Year EPN LPN SPN
External £0 £377,564 £0
Internal £0 £17,112 £0
Total £0 £394,676 £0
The costs have been allocated to LPN as the trial is being carried out in
this licence area.
Expenditure in Previous
(IFI) Financial Years This is a new project for 2012/13.
Total Project Costs
(Collaborative +
External +
UK Power Networks)
£ 394,676
Projected 2013/14
costs for UK Power
Networks
Project Completed
Technological Area and
/ or Issue Addressed by
Project
The project aims to address potential issues in the safety of operating a distribution network, from the exposure of the public and UK Power Networks personnel to potentially hazardous contact voltages present on street furniture. Additionally, the project will look to improve the knowledge of asset condition, via the detection of defects on distribution network underground assets. This will be achieved from the evaluation of technology and working methods not previously used in the United Kingdom.
Type(s) of Innovation
Involved Incremental
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
15 -1 16
Expected Benefits of
Project
Benefits are expected to include:
The early detection of potentially hazardous contact voltages present on street furniture located in the public highway
Reduction in the number of incidents involving the general public being exposed to potentially hazardous voltages present on street
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furniture
Detection of defects on underground cables and associated assets such as joints and link boxes, which were not observed during normal routine inspections
Expected Timescale to
Adoption N/A
Duration of benefit
once achieved N/A
Probability of Success 50%
Project NPV (Present
Benefits – Present
Costs) x Probability of
Success
Small
Potential for Achieving
Expected Benefits
Unfortunately the system did not perform as expected. It detected a
small number of defects in the trial area, but these were only above
ground, and below ground defects were not detected.
Expected benefits were not achieved during the trial and it is unlikely
that the expected benefits would be realised from a business as usual
deployment of the system.
Project Progress
March 2013
The trial took place ahead of the London 2012 Olympics at locations
where a large number of people were expected to be in the public
highway.
The evaluation of results has shown that the system is capable of
detecting potentially hazardous contact voltages present on street
furniture in the public highway, but the cost of surveying large urban
areas compared to the number of incidents found is prohibitive.
Additionally, a large number of the electrical defects identified were
found to be on the internal wiring within the street furniture, rather than
the DNO’s low voltage network. When such defects were detected, they
were made safe by removing the cut out fuse, and the defects were
reported to the appropriate local authorities.
The technology provider claimed that the system was also capable of
detecting cable faults that were developing underground, such as link
box defects. The work carried out showed that no such defects could be
detected, even when a fault was known to be present.
Collaborative Partners N/A
R&D Provider Power Survey Company
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National Underground Assets Group (NUAG) (Completed)
Description of Project
This project is being carried out as part of the National Underground Asset Group (NUAG). The aim of this project is to develop and trial the concept of having a UK-wide IT portal to enable anyone planning to undertake excavation in the highway or on private land to request information about the location of utility assets so as to prevent utility strikes and injury to workers, and improve joint working between utilities.
Expenditure for
Financial Year
EPN LPN SPN
External £0 £0 £0
Internal £0 £0 £0
Total £0 £0 £0
The costs have been allocated in proportion to the length of underground
cable installed in each of the three licence areas.
Expenditure in Previous
(IFI) Financial Years
External £50,000
Internal £4,522
Total £54,522
Total Project Costs
(Collaborative +
External + UK Power
Networks)
£600,000 Projected 2013/14 costs
for UK Power Networks Project Completed
Technological Area and
/ or Issue Addressed by
Project
If applicable only
Reducing utility strikes and injury to workers excavating near utility
assets.
Type(s) of Innovation
Involved Incremental
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
11.2 -8 19.2
Expected Benefits of
Project
Reduce the number of utility strikes
Improve safety for teams undertaking excavations
Improve cross sector utility visibility of underground assets
Expected Timescale to
Adoption 2013
Duration of benefit once
achieved On-going
Probability of Success High
Project NPV (Present
Benefits – Present
Costs) x Probability of
Success
Small
Potential for Achieving
Expected Benefits
The trial run by NUAG has been completed during the period April 2012
to March 2013.
The portal will not be adopted by UK Power Networks.
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Project Progress
March 2013
The trial undertaken over the last 12 months has proven that sharing
information using the IT portal is no better than the electronic map
system that UK Power Networks has been running for a number of
years.
Furthermore, as a user UK Power Networks did not find it easier to get
the location of asset information from other utilities.
On this basis, UK Power Networks (alongside other utilities) have given
notice to NUAG that we will not be supporting the development of the
NUAG solution any further.
Collaborative Partners
Thames Water (via UKWIR), Southern Gas Networks, National Grid
Gas; Transport for London, City of London Corporation, Technology
Strategy Board (TSB) and BT Openreach.
R&D Providers NUAG with ENVISTA as the main technology provider
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Tree Growth Regulator
Description of Project
The project is investigating the effect of a tree growth regulator (TGR)
on tree vitality and growth rates. Six field trial sites have been
established, supported by thirteen observational sites throughout the UK
to represent a diverse range of bio-climatic zones. There are two sites in
each of the participating network operator’s licence areas. Tree species
selected for TGR evaluation were chosen to represent those that occur
commonly near overhead networks, and where both the landowner and
the DNO may find mutual benefit in using TGRs to manage growth and
health of trees.
Expenditure for
Financial Year
EPN LPN SPN
External £1,179 £1 £421
Internal £44 £0 £16
Total £1,222 £1 £436
The costs have been allocated in proportion to the length of overhead
lines in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £89,211
Internal £11,101
Total £100,312
Total Project Costs
(Collaborative + External
+
UK Power Networks)
£715,000 Projected 2013/14 costs
for UK Power Networks
External £ 17,600
Internal £1,000
Total £18,600
Technological Area and
/ or Issue Addressed by
Project
Ability of tree growth regulators to manage rate of vegetation growth
and reduce maintenance costs, whilst improving vitality of vegetation.
Type(s) of Innovation
Involved Significant
Project Benefits
Rating
Project
Residual Risk
Overall Project
Score
15.4 -2 17.4
Expected Benefits of
Project
The expected outputs from the project will be data and information on
the effect of paclobutrazol (PBZ) on tree growth rates across a range of
species and bioclimatic areas. This data will be used to apply for a
licence for the use of PBZ for utility vegetation management.
PBZ could then be used as part of utility vegetation programmes to
reduce growth rates on restricted cut sites and reduce overall vegetation
management costs. This would also reduce the disturbance to
landowners and the high costs of returning each year to maintain
clearances from locations where vegetation management is limited.
Expected Timescale to Adoption in 2014 Duration of benefit once 20 Years
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Adoption achieved
Probability of Success 75%
Project NPV (Present
Benefits – Present
Costs) x Probability of
Success
>£1,000,000
Potential for Achieving
Expected Benefits
All objectives to date have been achieved.
There is a strong potential that the project will deliver the expected
benefits.
Project Progress
March 2013
During 2009 six field trials were established supported by 13
observational sites to study the effects of the plant growth regulator
paclobutrazol (PBZ) on tree vitality and growth.
In year one (the year that PBZ was applied) very little influence of
PBZ on tree vitality at each site was observed
In year two, a significant influence was recorded at each field site
By year three the influence had reduced indicating that the trees did
not respond as significantly as in year two
This year’s results support the results obtained in the previous year
suggesting that the effects after three years are starting to “wear off” in
some but not all species of tree. Effects of PBZ on vitality and growth
varied between tree species but, irrespective of tree species or field site
location, no phototoxic symptoms have been observed.
The project is now entering its final year and the data collected in this
year will complete the field trials. This data will then be analysed and the
results will be used to obtain a license for the use of PBZ to control
vegetation in the vicinity of electricity networks.
Collaborative Partners Scottish and Southern Energy, Western Power Distribution, Northern
Powergrid
R&D Provider Bartlett Tree Experts, ADAS
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Overhead Line Incipient Fault Location
Description of Project
This project aims to trial a solution to locate faults on overhead lines,
using detection points installed on the HV overhead network.
The objectives are to:
Help identify more rapidly network sections containing faults
Predict and accurately locate a potential fault on the system before
it occurs
Expenditure for
Financial Year
EPN LPN SPN
External £82,361 £39 £29,400
Internal £15,447 £7 £5,514
Total £97,808 £46 £34,914
The costs have been allocated in proportion to the length of overhead
lines in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £305,668
Internal £27,715
Total £333,383
Total Project Costs
(Collaborative + External
+
UK Power Networks)
£659,000
Projected 2013/14 costs
for UK Power Networks
External £116,000
Internal £89,000
Total £205,000
Technological Area and
/ or Issue Addressed by
Project
Overhead line fault mechanisms and the extent to which they are
associated with recognisable, repeatable waveforms
The location of faults based on measuring time-of-arrival of the
waveforms
Type(s) of Innovation
Involved Radical
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
16 0 16
Expected Benefits of
Project
The expected benefits of the project are:
Development of a proactive approach towards decreasing
interruption duration
Reduce the switching required to locate faults
Reduction in recurring faults
Expected Timescale to
Adoption 2014
Duration of benefit once
achieved >10 years
Probability of Success 50% Project NPV (Present
Benefits – Present Costs) £215,000
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x Probability of Success
Potential for Achieving
Expected Benefits
Four 11kV circuits have been identified for installation of the system.
The circuits have a relatively high historical fault-rate which should give
a greater amount of data for analysis and also a higher chance of
realising the benefits in the trial stage.
Project Progress
March 2013
An Operating Standard covering the installation and operation of the
equipment (to ensure that the deployment of the technology can be
undertaken safely) has been written and approved. UK Power Networks
requested that additional testing is undertaken by Altea to provide
confidence that the equipment is safe and complies with international
standards. The testing was successfully carried out in April 2012, and
confirmed that the technology is suitable for connection to our 11kV
networks.
Equipment has been delivered to enable the completion of installations
to two of the identified circuits. Once the system is installed and proven
to be functioning as expected, a further two circuits will be equipped.
Collaborative Partner Electricity North West
R&D Providers ALTEA B.V
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Earthing Information System
Description of Project
The Earthing Information System project will develop a Geographical
Information System (GIS) to assist the installation of earthing systems
for secondary distribution and pole-mounted substations. The system
will provide a graphical presentation of ground conditions and predict
the type and quantity of earthing required for a particular earthing
resistance.
Earthing rural substations can be very labour intensive, with the need to
drive earthing rods vertically downwards into the ground to a depth of
12 metres, to achieve the necessary 10 ohm resistance. Rods are
usually driven by pneumatic tools or by hand. Where hard ground
restricts the depth of installation an array of rods may be installed at
shallower depth, or an earthing system is extended some distance from
the substation to achieve the required resistance. This project aims to
improve the prediction of costs of earthing before on-site work
commences by providing a desk-top indication of the earthing required.
Expenditure for
Financial Year
EPN LPN SPN
External £36,153 £23,176 £22,954
Internal £2,284 £1,464 £1,450
Total £38,437 £24,640 £24,404
The costs have been allocated in proportion to the number of customers
connected in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £437,165
Internal £51,611
Total £488,776
Total Project Costs
(Collaborative +
External +
UK Power Networks)
£590,509 Projected 2013/14 costs for
UK Power Networks
External £12,252
Internal £2,000
Total £14,252
Technological Area and
/ or Issue Addressed by
Project
A network-wide information system that will help network planners to
improve planning and costing of new and replacement earthing
installations.
Type(s) of Innovation
Involved Significant
Project
Benefits Rating
Project Residual
Risk
Overall Project
Score
9.4 0 9.4
Expected Benefits of
Project
The expected benefits are:
Accurate estimation of the cost of installation of rural ground earthing systems
Advice on the number and techniques required for earthing installations
Improved employee safety
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Expected Timescale to
Adoption 2014
Duration of benefit once
achieved 20 Years
Probability of Success 70%
Project NPV (Present
Benefits – Present Costs)
x Probability of Success
£100,000
Potential for Achieving
Expected Benefits
The potential for integrating the outputs of this project into the business
is high. An engineering design standard has been produced to
communicate the earthing information system to the business.
The use of the earthing information system is also being incorporated
into the various earthing design and construction standards as they are
reviewed and updated.
Project Progress
March 2013
Over the last year, the project has further refined the soil resistivity model based on soil samples and laboratory investigation:
The earthing maps have been revised to include both the Phase I (vertical rod preference) and Phase II (horizontal conductor and shallow vertical rods preference) earthing prognoses along with flags to indicate areas that are susceptible to climate change
Climate modelling has been carried out to determine areas that might be prone to soil moisture deficit up to the 2080s. These have been combined with estimates of soil and geology susceptibility to climate change (based on the composition of the soil and geology) in order to generate a risk matrix of areas where earthing systems might be prone to deviation from the original specification
A series of qualitative map layers have been created for the different time periods/climate models, and have been added as flags to the earthing maps. The qualitative climate modelling has been used to generate, through modelling, some estimates of the quantitative changes in soil and geology resistivity that might occur from climate change. A flag for the maps to indicate areas that are prone to seasonal variations is also under construction
The project will now concentrate on bringing all of the data and maps
together for incorporation into the UK Power Networks’ NetMAP GIS
system.
Collaborative Partner Western Power Distribution
R&D Providers British Geological Survey and Cranfield University
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Developing Long Term Asset Risk Replacement Modelling
Description of Project
The aim of this project is to redefine and expand currently limited statistical models, to create a wider and more accepted standard for use with higher volume and lesser data populated asset categories. Complex risk modelling programmes require extensive amounts of data to work. The asset groups selected in this project (e.g. civil assets) are in the stages of having their data completeness, accuracy and timeliness improved. The aim is also to provide a capable platform for calculating Health and Criticality Index for low value high volume assets such as cable pits, based on limited amount of data, and plan interventions. The model methodology produced will be used as the first line approach for modelling new asset categories, before progressing them to more complex modelling tools.
Expenditure for
Financial Year EPN LPN SPN
External £24,845 £13,700 £15,757
Internal £921 £508 £584
Total £25,766 £14,208 £16,341
The costs have been allocated in proportion to number of
substations in each licence area.
Expenditure in Previous
(IFI) Financial Years This is a new project for 2012/13.
Total Project Costs
(Collaborative +
External +
UK Power Networks)
£152,000
Projected 2013/14
costs for UK Power
Networks
External £90,260
Internal £7,500
Total £97,760
Technological Area and
/ or Issue Addressed by
Project
Modelling of future condition of assets and recommend
replace/refurbish/maintain decisions on individual components
Inconsistency in asset modelling and information gathering
Preparation for an optimisation which will include plant loading in
distribution assets or child asset aggregation in civil assets as
parameters
Type(s) of Innovation
Involved Incremental
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
10.2 -6 16.2
Expected Benefits of
Project
Benefits are expected to include:
Greater consistency of asset health data and forecasts
Enhanced trending capability
Improved confidence of long asset planning
Integration of risk based approach to asset management
Expected Timescale to
Adoption 2013
Duration of benefit
once achieved 5 years
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Probability of Success 75%
Project NPV (Present
Benefits – Present
Costs) x Probability of
Success
£200,000
Potential for Achieving
Expected Benefits
The models have been collaboratively designed by UK Power Networks
Asset Engineers and Decision Lab to ensure that all the available
knowledge is used.
Excel models have been provided as demonstration versions.
This project is on track to be completed by July 2013.
Project Progress
March 2013
Initial models have successfully been demonstrated to UK Power
Networks’ Asset Engineers. A number of suggestions were made to
improve the modelling capabilities (e.g. by including additional condition
measures) and improve the performance of the platform.
A significant achievement has been to bring Civil assets in line with
electrical assets, providing UK Power Networks with the capability to
model HIs and CIs for key assets whose primary task is to protect the
electrical assets. The model uses age and condition data to produce a
final risk score that can be used to plan future intervention strategies.
Several reports on modelling flow, data specification and modelling
methodology have been issued to UK Power Networks.
Once completed, the project will provide a platform to model LV
Switchgear, Linkboxes, Distribution Transformers, Cable Pits and Civil
Assets.
Collaborative Partners N/A
R&D Provider Decision Lab
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Development of technologies to extend the life of Link boxes and mitigate the impact of cable pit disruptive failures
Description of Project
UK Power Networks has been working closely with Black & Veatch to develop a strategy for the management of cable pits, and to assess new technologies for use on cable pit covers. The strategy is similar to what is used in the management of link boxes and has been incorporated into the cable pit inspection programme. This will enable UK Power Networks to prioritise the inspection of assets. Through the inspection programme, key asset condition data will be recorded and used to model future asset condition and replacement strategies. Safety risks will be reduced through a mitigation strategy involving the use of innovative cable pit footway and highway cover designs not previously used in the UK. These covers will have the capability to vent cable pit chambers, be locked and tethered, and have the potential for built in monitoring equipment capable of sending information about the state of the cable pit and covers to a central location. In addition, the project will assess the potential for link box refurbishment. Work will be carried out at the ERA Technology laboratory to inspect 50 link boxes that have been removed from the distribution network, in order to establish the root causes of failure, together with possible mitigation of defects. Work is also planned on prospective short circuit current (PSCC) testing and cyclic loading tests, and testing will be undertaken to determine the suitability of a new frame and cover system.
Expenditure for
Financial Year
EPN LPN SPN
External £36,883 £150,176 £29,253
Internal £1,368 £5,571 £1,085
Total £38,251 £155,747 £30,338
The costs have been allocated in proportion to the number of link boxes
and cable pits in each licence area.
Expenditure in Previous
(IFI) Financial Years This is a new project for 2012/13.
Total Project Costs
(Collaborative +
External +
UK Power Networks)
£ 714,000
Projected 2013/14
costs for UK Power
Networks
External £ 468,000
Internal £ 20,000
Total £ 488,000
Technological Area and
/ or Issue Addressed by
Project
Implementation and evaluation of novel retrofit solutions to mitigate
the impact of cable failures within pits Risk based asset management of cable pits Investigation of link box failure mechanisms and potential innovative
methods for link box refurbishment to prolong asset life
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Type(s) of Innovation
Involved Development
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
12.8 -1 13.8
Expected Benefits of
Project
Benefits are expected to include:
Reduced risks to the public and UK Power Networks staff, through
the continued implementation of mitigation measures
Greater consistency of asset health data and forecasts
Enhanced civil condition assessment capability
Improved confidence in long term electrical asset degradation
models and early warning of developing faults
Improved integration of risk based approach to asset management
Expected Timescale to
Adoption 2013
Duration of benefit
once achieved 20 Years
Probability of Success 80%
Project NPV (Present
Benefits – Present
Costs) x Probability of
Success
£100,000
Potential for Achieving
Expected Benefits
There is high confidence that the work undertaken to produce and
implement a cable pit mitigation strategy will be successful. Confidence
in the effectiveness of the mitigation strategy is expected to build once
inspections progress to a business as usual (BAU) activity.
As the strategy moves into BAU, its success will have a large
dependence on the quality of asset condition data. Therefore, improved
training and inspector understanding of condition and defects will
assure the success of the strategy.
While it is unlikely that incidents involving cable pits will be completely
eliminated, the work to deploy new cable pit footway and highway cover
designs will reduce the impact of these incidents. A number of trial
covers have been installed
Work to date on link boxes has already increased our understanding of
link box failure mechanisms, and it is likely that the next phase of testing
will enhance our link box asset knowledge. While it is currently too early
in the project to determine whether the expected benefits from link box
refurbishment or modified frame covers will materialise.
Overall progress on the project has been positive and it is likely that the
benefits will be realised.
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Project Progress
March 2013
Following a number of link box inspections, a Reliability Centred
Maintenance (RCM) report was written in December 2012. It outlines
failure modes, and recommendations on potential design improvements
that could be made to link boxes.
Using the conclusions drawn in the RCM report, a risk-based
assessment model has been created to identify and consider a risk
reduction strategy.
In addition a new link box inspection policy and procedure has been
issued to link box inspectors.
An enhanced cable pit inspection programme which prioritises the
inspection of pits, and includes newly developed policies and
procedures to support the cable pit inspections has been developed.
The inspection programme is expected to be integrated into BAU
activities by June 2013, with 500 inspections expected per week.
As it is unlikely that incidents involving cable pits will be completely
eliminated, work on mitigations and innovations to reduce the risk of
cable failures within pits has also been undertaken. This has led to the
trial installation of four new composite cable pit covers designed to vent
any build-up of gases.
To further enhance the categorisation and identification of cable pits, an
asset health and criticality model has been developed.
Collaborative Partners N/A
R&D Provider Black & Veatch Ltd, ERA Technology Ltd, SSC Ltd
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Detection of Broken and Low Hanging Conductors
Description of Project
Detection of broken and low hanging conductors is a long standing
issue with UK DNOs and there is no proven technology for the reliable
detection of this condition commercially available.
This project will explore new concept for detecting of Broken and Low Hanging Conductors
Expenditure for
Financial Year EPN LPN SPN
External £31,898 £15 £11,386
Internal £1,183 £0 £422
Total £33,081 £15 £11,808
The costs have been allocated in proportion to the length of overhead
lines in each licence area.
Expenditure in Previous
(IFI) Financial Years This is a new project for 2012/13.
Total Project Costs
(Collaborative +
External +
UK Power Networks)
£ 160,000
Projected 2013/14
costs for UK Power
Networks
External £112,000
Internal £3,000
Total £115,000
Technological Area and
/ or Issue Addressed by
Project
Review of currently available products that may be capable of detecting broken and low hanging conductors. Following on from this work, new concepts will be explored to determine whether there is potential for development of a new solution.
Type(s) of Innovation
Involved Incremental
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
13.4 -2 15.4
Expected Benefits of
Project
Identification and potential development of a solution or solutions
for the detection of broken and low hanging conductors
Increased safety through successful detection and disconnection
Expected Timescale to
Adoption 2014
Duration of benefit
once achieved 20 Years
Probability of Success 60%
Project NPV (Present
Benefits – Present
Costs) x Probability of
Success
<£100,000
Potential for Achieving
Expected Benefits
Whilst there is potential for demonstrating benefits, there are many
factors that could influence the success of detection, such as the fault
position and fault duration.
If currently available commercial products can be configured to detect
the required conditions, then it is anticipated some benefits in detection
will be derived quickly.
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Project Progress
March 2013
A review of commercially available solutions and assessment of current
practices has been completed. It focussed on the review of high
impedance fault detection currently available on the market and
practices adopted by UK DNOs. This indicated that whilst there are
products that claim to have the capability to detect broken conductors,
the measurement and detection methods are not reliable and the
sensitivity to faults at the end of long or lightly loaded feeders could not
be guaranteed.
An assessment focussing on the use of mechanical sensors to detect
broken and low hanging conductors has been undertaken. This
concluded that mechanical detection is prohibitively expensive if applied
to the whole of the overhead line network, and a targeted approach to
higher risk areas (i.e. locations where a failure is more likely to result in
the public coming in contact with the conductor) is more appropriate.
Next steps
Further work is required to understand the effects on conductor tension
as a result of events such as stay failure, broken supports, etc. Once
this is concluded, the use of devices such as load cells, which can
detect mechanical changes and convert them into electrical signals,
may be considered and deployed on a trial basis. Further work is also
required to better understand capabilities of existing products, and
decide whether to engage in further collaborative developments.
An investigation into the detection of broken conductors through change
of Sensitive Earth Fault (SEF) over time will be carried out.
Investigations into the detection through rate of change of capacitance
will not be progressed due to a high probability of it not being
achievable.
Voltage monitoring at the circuit ends will also be investigated. This
would require the installation of voltage monitoring devices on all
phases at circuit ends in order to be completely effective. A lower cost
option would be to only deploy the monitoring devices on circuit ends, or
intermediate positions close to high risk areas.
This part of the project will determine the most effective means of
deployment and issues with establishing the required communications
links.
Collaborative Partners None at this stage.
R&D Provider EA Technology Ltd
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Earthing Design Tool
Description of Project
The project will develop an Excel based earthing design tool that can be used easily by distribution planning engineers and connections designers to design the earthing for a secondary distribution (11kV/400V) substation. This project uses the outputs from the HV/LV Earthing Transfer IFI project (reported under ENA Collaborative Programme section).
Expenditure for
Financial Year EPN LPN SPN
External £25,264 £16,195 £16,040
Internal £3,097 £1,985 £1,967
Total £28,361 £18,180 £18,007
The costs have been allocated in proportion to the number of customers
in each licence area.
Expenditure in Previous
(IFI) Financial Years This is a new project for 2012/13.
Total Project Costs
(Collaborative +
External +
UK Power Networks)
£85,000 Projected 2013/14 costs
for UK Power Networks
External £13,000
Internal £2,000
Total £15,000
Technological Area and
/ or Issue Addressed by
Project
Currently, the only tools available to carry out earthing studies are very complex and costly, and therefore difficult to use by distribution planners and connections designers. This project will address this deficiency by providing a basic earthing design tools that encapsulates the complete earthing design process.
Type(s) of Innovation
Involved Development
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
11 -3 14
Expected Benefits of
Project Improved productivity at the design stage of new substation projects
Expected Timescale to
Adoption 2014
Duration of benefit once
achieved 10 years
Probability of Success 90%
Project NPV (Present
Benefits – Present Costs)
x Probability of Success
£100,000
Potential for Achieving
Expected Benefits
The potential for achieving the expected benefits is high but is subject to
completion of user acceptance testing.
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Project Progress
March 2013
The first version of the tool is being used by designers and planning
engineers. Acceptance testing is taking place and refinements are to
be made over a six month period.
See case study in Highlights section for further details.
Collaborative Partners None
R&D Provider Earthing Solutions
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Leveraging Industrial and Commercial Demand Response and Dispatchable Generation
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Bankside Heat Transfer
Description of Project
Substation transformers generate heat, particularly during peak loads.
This heat is normally lost to the environment, often through energy-
intensive forced cooling. The upgraded substation at Bankside, adjacent
to the Tate Modern, has used transformers with water cooled heat
exchangers. It is proposed that the waste heat from the transformers
will be used by the Tate Modern to assist with their space heating. This
will benefit the Tate by providing low carbon heat. The benefits for UK
Power Networks are that less energy will need to be expended within
cooler fans at the substation, and lower maintenance and replacement
cost will be incurred. The overall carbon footprint of the site and assets
will be reduced.
Expenditure for
Financial Year
EPN LPN SPN
External £0 £0 £0
Internal £0 £0 £0
Total £0 £0 £0
The costs have been allocated to LPN as the trial is being carried out at
Bankside substation in London.
Expenditure in Previous
(IFI) Financial Years
External £719,080
Internal £95,035
Total £814,115
Total Project Costs
(Collaborative + External
+
UK Power Networks)
£846,115 Projected 2013/14 costs for UK
Power Networks
External £ 30,000
Internal £ 2,000
Total £ 32,000
Technological Area and
/ or Issue Addressed by
Project
The oil-to-water heat exchangers at this scale and for this purpose are
novel, as is the specific heating arrangement.
Type(s) of Innovation
Involved Significant
Project Benefits
Rating
Project
Residual Risk
Overall Project
Score
4 1 3
Expected Benefits of
Project
Benefits are expected to include:
Heat used by a third party replacing a high CO2 heat source
Use of energy that would otherwise be lost
Fewer maintenance interventions for cooling
Less energy expended for cooling via less auxiliary electricity
consumption
Lower noise level from coolers
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Expected Timescale to
Adoption 2013
Duration of benefit once
achieved. Expected to be
commissioned and handed over
to the Tate in late 2013
20 Years
Probability of Success 75%
Project NPV (Present Benefits –
Present Costs) x Probability of
Success
£200,000
Potential for Achieving
Expected Benefits
The temperature of the water returning from the transformer heat
exchangers is not as high as predicted. This is primarily because of the
lower than expected load on the transformers and some heat losses in
the coolers. Work is planned in the second half of 2013 to attempt to
increase the water temperature by reducing the flow of water.
There is still the potential to provide benefits for a number of heat
applications. The objective is to pre-heat the general hot water supply at
the Tate Modern, reducing the amount of energy required from the main
boilers to raise the water to the required temperature.
The Tate Gallery is currently exploring the use of this heat in the new
gallery.
Project Progress
March 2013
The work at the Tate is completed permitting the transformer cooling
water to flow to the Tate boiler room. Some small wiring modifications
are in the final stages to permit monitoring at the Tate control centre.
Collaborative Partner Tate
R&D Providers Wilson Transformers and Arup
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Automated LTDS Diagrams (Completed)
Description of Project
Major demand and generation customers rely on the knowledge of how and where they connect to the network, and public information on the network is contained in our Long Term Development Statement (LTDS). Currently the LTDS and Week 28 (annual report to National Grid) reports are being generated using a variety of software tools, including the network modelling tools Distribution Network Information System (DINIS) and Power System Simulator for Engineering (PSS/E). Information was extracted from these tools and processed in Excel to prepare the final report. This project was initiated to investigate if automating the production of LTDS and week 28 reports is possible with the same structure for all the DNO licence areas. As part of this project, a set of professional schematics for the LTDS, and an automatic report for Week 28 are developed within the existing modelling tool – Digsilent PowerFactory.
Expenditure for
Financial Year
EPN LPN SPN
External £46,589 £29,865 £29,581
Internal £1,728 £1,108 £1,097
Total £48,317 £30,973 £30,678
The costs have been allocated in proportion to the number of customers
connected in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £176,269
Internal £15,941
Total £192,210
Total Project Costs
(Collaborative +
External +
UK Power Networks)
£302,178 Projected 2013/14 costs
for UK Power Networks Project Completed
Technological Area and
/ or Issue Addressed by
Project
This project addressed the following issues:
Multiple tools for LTDS and Week 28 reporting
The complex calculations involved are prone to human errors
Takes a two person-year effort for the production of reports once a
year
Type(s) of Innovation
Involved Incremental
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
7 -2 9
Expected Benefits of
Project
The benefits are expected to include:
Faster production of LTDS and Week 28 reports
Improved consistency of data models
Enables UK Power Networks to more efficiently address the various
queries from National Grid and general public on demand
Automated Reports will enable more accurate reporting and reduce
manual work
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Infrastructure planners no longer have to produce the Fault Level
tables in the LTDS manually
Schematics would no longer need to be maintained in Microsoft
Visio
A single source of data removes the need to align and check data
from separate sources
Expected Timescale to
Adoption 2012
Duration of benefit once
achieved 5 years
Probability of Success 100%
Project NPV (Present
Benefits – Present
Costs) x Probability of
Success
£ 300,000
Potential for Achieving
Expected Benefits
The project has been successfully completed.
Project Progress
March 2013
Further work to align the network model to National Grid structure for
Week 28 outputs was successfully concluded in November 2012. The
2012 Week 28 output and LTDS were completed using the new
automated tool.
Additional improvements were identified and implemented during the
production of the outputs, which primarily related to the model structure
and naming conventions. This work was funded by UK Power Networks.
The development of an internal process to improve the efficiency of
outputs verification will conclude in 2013.
Collaborative Partners N/A
R&D Provider Tata Consultancy Services
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Managing Residential and Small and Medium Enterprise (SME) Consumer Demand
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Supergen 3 HiDEF Highly Distributed Energy Futures
Description of Project
The HiDEF programme, funded by the EPSRC (Engineering and
Physical Sciences Research Council) researches the essential
elements of a decentralised system that could be implemented over the
period 2025 to 2050, to enable all end users to participate in system
operation and real-time energy markets.
Expenditure for
Financial Year
EPN LPN SPN
External £9,227 £5,915 £5,858
Internal £373 £239 £237
Total £9,600 £6,154 £6,095
The costs have been allocated in proportion to the number of customers
in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £61,000
Internal £5,704
Total £66,704
Total Project Costs
(Collaborative + External
+
UK Power Networks)
£4,500,000 Projected 2013/14 costs
for UK Power Networks
External £0
Internal £1,000
Total £1,000
Technological Area and
/ or Issue Addressed by
Project
The HiDEF programme has 5 workstreams: Decentralised Energy,
Decentralised Control, Decentralised Network Infrastructure,
Decentralised Participation, Decentralised Policy and Macro Impact
Assessment.
Type(s) of Innovation
Involved Radical
Project
Benefits Rating
Project
Residual Risk
Overall Project
Score
7.2 -2 9.2
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Expected Benefits of
Project
Outputs from the HiDEF workstreams will inform debates that are
current in the industry and enable the following benefits to be realised:
Models of single and multiple DER (Distributed Energy Resource)
units have been developed to assess the thermodynamic analysis,
life cycle assessment and environmental cost benefit analysis,
providing a quantification of performance
Development of control solutions for single units, cells containing
multiple DERs, and multiple cells, with a focus on security and
resilience of communications and control systems
Support and investment guidance for future decentralised network
operation through the development of HV/LV architectures and
planning tools
Design of a distributed market place, to enable the investigation of
market based response, trading contracts and products, defining the
components essential to market realisation
Inform future policy decisions by reviewing current policy delivery
mechanisms in the UK, comparing market structures & examining
the potential for alignment with various market aggregations
Expected Timescale to
Adoption
Year 2013
onwards
Duration of benefit once
achieved 20 Years
Probability of Success 25%
Project NPV (Present
Benefits – Present Costs)
x Probability of Success
£2,000,000
Potential for Achieving
Expected Benefits
Good progress has continued, and a number of briefing documents have been submitted to the government. http://www.supergen-hidef.org/Publications/Pages/BriefingPapers.aspx Industrial partners have utilised the models developed in their LCNF projects, and training / dissemination workshops have been planned in September 2013, which will ensure that learning is communicated effectively.
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Project Progress
March 2013
The Decentralised Energy Workstream has completed the realisation of open source models of energy storage, energy conversion and energy demand components. The library of domestic building models has now been complemented with commercial building models, featuring hybrid and low carbon systems. Further progress has been made in the realisation and testing of new cell (small network area) control solutions using the hardware rigs and simulation environments. A number of new power and energy system analytical techniques and tools have been developed in the Decentralised Network Infrastructure workstream. These have been applied to the analysis of industrial case studies. Projects at Ebbw Vale, Ashton Hayes and Shetland have been supported, and the data sets and tools in relation to DSM, EV & HP, thermal and electrical storage refined using the experience gained. The Decentralised Participation team have developed stochastic optimisation techniques and novel pricing techniques that help maximise the expected portfolio of DG and DR services. Furthermore, the hardware platform showcasing frequency response functions for smart meters has now been demonstrated at a smart meter exhibition.
The Decentralised Policy and Macro Impact Assessment team has
continued their assessment of the effectiveness of alternative policy
measures at locations including Glasgow, Brighton & Hove, and Milton
Keynes. The ability to conduct macro-economic modelling, incorporating
the impact of renewables and advanced generation deployment has
been enhanced through improvements to the established Computable
General Equilibrium model to incorporate household energy demands.
This will now feature in on-going economic modelling activity.
The project continues to support a number of engagement and impact
case studies, including a number of LCNF projects. The value of HiDEF
datasets, simulation & analysis tools, and models have been assessed
with academic partners, industrial colleagues, community groups, and
agency staff. This has been complemented with dissemination and
engagement, including 37 new publications, a HiDEF workshop in
London regarding “The Future of Community Energy”, and participation
in a variety of conferences and meetings.
Collaborative Partners
EPSRC and the following industrialists: Community Energy Scotland,
Delta Energy & Environment, Intelligent Power Systems, National Grid,
Western Power Distribution, Scottish Power Energy Networks, Scottish
and Southern Energy.
R&D Provider
University of Strathclyde supported by: University of Bath, Cardiff
University, University of Oxford, Loughborough University, Imperial
College London.
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Active Distribution networks with full integration of Demand and distributed energy RESourceS (ADDRESS) (Completed)
Description of Project
The project aims to deliver a comprehensive commercial and technical
framework for the development of “Active Demand” in the smart grids of
the future. ADDRESS started in June 2008 and is investigating how to
effectively stimulate the participation of domestic and small commercial
consumers in the power system markets. The project also addresses
the provision of services to different power system participants.
ADDRESS is European Commission funded FP7 project.
Expenditure for
Financial Year
EPN LPN SPN
External £0 £0 £0
Internal £0 £0 £0
Total £0 £0 £0
The costs have been allocated in proportion to the number of customers
connected in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £-4,864
Internal £12,029
Total £7,165
Total Project Costs
(Collaborative +
External +
UK Power Networks)
£12,600,000
Projected 2013/14
costs for
UK Power Networks
Project Completed
Technological Area and
/ or Issue Addressed by
Project
The project aims to develop new concepts, strategies and architectures
for services provided by demand and distributed energy resources
(distributed generation and storage) on distribution grids. This entails a
full integration and market-based exploitation of the flexibilities of the
distributed energy resources of the distribution network.
Type(s) of Innovation
Involved Incremental
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
11.2 -2 13.2
Expected Benefits of
Project
ADDRESS will develop technical solutions both for the consumers’
premises and at a power system level. The solutions will enable active
demand and allow real-time response to requests from markets and/or
other power system participants.
Expected Timescale to
Adoption Year 2015
Duration of benefit
once achieved 10 Years
Probability of Success 75%
Project NPV (Present
Benefits – Present
Costs) x Probability of
Success
This project is expected
ultimately to deliver
benefits in the order of
millions of pounds.
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Potential for Achieving
Expected Benefits
The trials undertaken in France, Spain and Italy, have shown that
demand response services can be achieved. However the operating
costs and the immaturity of supporting market frameworks are indicative
that further information and education is required for large scale uptake.
Project Progress
March 2013
Over the last year, specifications and design of a cost/benefit analysis
tool for active demand deployment have been prepared. Various
business cases for customers, aggregators and DSOs have been
developed.
The field tests in Italy, France and Spain have started, but delays in
recruiting customers has meant that the results of the trials originally
expected in early 2013 have been delayed.
Results and findings from the field tests are expected to be published
mid 2013, when sufficient amount of information has been gathered and
analysed. These will then be used to populate and verify the business
cases developed.
Collaborative Partner
ADDRESS is an Integrated Project supported by the European
Commission under the 7th framework programme. The project website
is www.addressfp7.org
R&D Providers
University of Manchester,
Universidad Pontificia Comillas,
Università di Siena,
Università di Cassino,
ENEL Ingegneria e Innovazione,
VTT,
VITO,
Tecnalia,
KEMA,
Consentec
ENEL Distribuzione,
UK Power Networks,
Iberdrola Distribución Eléctrica,
Vattenfall
EDF-SA,
ENEL Distributie Dobrogea
ABB,
Landis+Gyr,
ZIV
Philips,
Electrolux,
RLtec
Ericsson Espańa,
Alcatel,
Current
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Home Based Flexible Demand Management (HBFDM)
Description of Project
The Technology Strategy Board (TSB) project is exploring how residential customers might be engaged in providing responsive demand and control the output of distributed generation on behalf of DNOs. The aim is to develop the scope for a technical solution, consumer proposition and business model which will allow for responsive demand to be utilised before the completion of the UK wide smart metering rollout, and without the involvement of investment from the electricity supplier.
The solution utilises PassivSystems’ open architecture energy management platform to create a scalable load management system, which will coordinate the grid and customer equipment to reduce peak loads. Interruptible demand will be managed remotely utilising broadband or GSM connectivity, without detrimentally impacting the occupant comfort.
PassivSystems control system will understand consumer requirements by monitoring real time environmental variables in the home to build a profile of occupant behaviour, and will utilise local weather data to identify load that may be shed in response to a future DNO requirement.
This project is complementary to the work taking place as part of Low Carbon London, where smart meters are being utilised to modify demand profiles of residential customers.
Expenditure for
Financial Year
EPN LPN SPN
External £-4,597 £-2,947 £-2,919
Internal £9,395 £6,023 £5,966
Total £4,798 £3,076 £3,047
The costs have been allocated in proportion to the number of customers
connected in each licence area.
50% of the UK Power Networks cost is funded by the TSB.
Expenditure in Previous
(IFI) Financial Years This is a new project for 2012/13.
Total Project Costs
(Collaborative +
External +
UK Power Networks)
£ 150,302
Projected 2013/14
costs for UK Power
Networks
External £0
Internal £17,458
Total £17,458
Technological Area and
/ or Issue Addressed by
Project
The project will investigate the potential for a DNO to leverage Residential Sector Demand Response Services, to address network constraints and/or reduce the impact of network events such as faults.
Type(s) of Innovation
Involved
Technological
substitution from
different
application
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
7 -3 10
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Expected Benefits of
Project
It is hoped a roadmap will be formulated which will guide the development and demonstration of a demand response platform for the residential sector.
Expected Timescale to
Adoption 2015
Duration of benefit
once achieved 10 Years
Probability of Success 30%
Project NPV (Present
Benefits – Present
Costs) x Probability of
Success
£100,000
Potential for Achieving
Expected Benefits
The project outputs will be delivered in September 2013.
There is a high confidence that some demand response can be
delivered by the residential trial participants. This confidence is based
on the automated aspects of the trial, and also aligns with other
residential demand response trials (via tariffs) such as Low Carbon
London.
Project Progress
March 2013
The UK Power Networks team has produced two reports to date:
HBFDM – Current and Future DNO Issues
HBFDM – Modelling Calculation DNO Costs
The main findings of these initial reports are around the uncertainty of
the value of demand response to DNOs. One question raised, which will
be answered as part of the project, is the difference between the
demand response requirements for normal network running
arrangements and outage scenarios (post network faults).
UK Power Networks are currently undertaking work covering the
following four topics:
How can a communication link be established between the home
and the grid?
Analysis of the current and future load growth, and how this will
translate to network reinforcement costs (with demand side action)
for UK Power Networks
How might the DNO reward consumers?
How might we overcome the regulatory barriers?
Collaborative Partners PassivSystems Limited
R&D Provider PassivSystems Limited
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New Options to Release Capacity at 11kV, 33kV and 132 kV
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Increased Capacity from Existing Overhead Line Routes
Description of Project
Re-conductoring overhead lines to increase their capacity can often be intrusive, requiring new structures, and as such may be less viable than installing the equivalent (but more expensive) cable circuit. This project is consolidating techniques for maintaining existing line routes and structures but providing greater ratings.
Expenditure for
Financial Year
EPN LPN SPN
External £115,519 £55 £41,236
Internal £22,061 £10 £7,875
Total £137,580 £65 £49,111
The costs have been allocated in proportion to the length of overhead
lines in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £96,906
Internal £9,190
Total £106,096
Total Project Costs
(Collaborative +
External +
UK Power Networks)
£850,000 Projected 2013/14 costs
for UK Power Networks
External £200,000
Internal £20,000
Total £220,000
Technological Area and
/ or Issue Addressed by
Project
Novel conductors for 33kV lines as well as 132kV lines
Re-tensioning and minor modifications to structures
Review of operating regimes (such as post-fault regimes)
Type(s) of Innovation
Involved Incremental
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
13 -4 17
Expected Benefits of
Project
The project aims to identify alternative, cheaper interventions to enable reinforcement / re-build of the line to be deferred. In particular, the project will develop a manual and training which articulates design options and trade-offs so that alternative options can be identified at an earlier stage in future projects.
Expected Timescale to
Adoption 1-2 years
Duration of benefit once
achieved 20 Years
Probability of Success 60%
Project NPV (Present
Benefits – Present
Costs) x Probability of
Success
£200,000
Potential for Achieving
Expected Benefits
One of the design solutions has been through a full technical design
review and has shown an extremely high likelihood of success. This has
resulted in a £6.36m saving in our current business plan.
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Project Progress
March 2013
The project is progressing well, and some of the techniques explored
(e.g. advanced thermal up-rating and dynamic line ratings) for
increasing line capacity are due to be implemented in the next few
months.
Two overhead line routes (a 132kV tower line and a 33kV wood pole
line) have been chosen and various design options reviewed and
assessed. It was determined that in both cases higher capacity is
available from carrying out relatively minor improvement works, which
allowed an increased maximum operating temperature to be applied to
the existing conductors. This has led to neither route being suitable for a
novel conductor, although research into the effects and application of
these conductors has been undertaken.
Collaborative Partners N/A
R&D Provider
Mott McDonald and Manchester University
(The project also builds on work carried out by EA Technology Ltd over
recent years in the Strategic Technology Programme Modules 2 and 5)
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Urban Transformer Substation
Description of Project
It is often difficult to reinforce circuits in densely populated areas mainly because there is limited physical space available. London substations were commonly built underground, making subsequent alterations expensive and potentially very disruptive during construction.
The project will evaluate if an urban distribution substation developed by a Spanish company (Twelcon) could help address these issues.
The urban substation houses an LV panel, Ring Main Unit (RMU), Remote Terminal Unit (RTU) and Transformer (up to 1,000 kVA). Twelcon currently use continental equipment in the substation; hence development and further testing may be required to ensure that components meet UK Power Networks specifications and perform efficiently and safely within the urban substation environment. The Twelcon substation also has four backlit advertising panels that could be used for public information.
Expenditure for
Financial Year
EPN LPN SPN
External £0 £0 £0
Internal £1,124 £620 £713
Total £1,124 £620 £713
The costs have been allocated in proportion to the number of
substations in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £18,805
Internal £1,985
Total £20,790
Total Project Costs
(Collaborative +
External +
UK Power Networks)
£32,247 Projected 2013/14 costs
for UK Power Networks
External £8,000
Internal £1,000
Total £9,000
Technological Area and
/ or Issue Addressed by
Project
Reinforcement of stressed areas of the distribution network at 11KV
Relocation of substations which are currently difficult to access,
especially where asset replacement is likely to be expensive
Provide the means to serve urban electric vehicle (EV) charging
infrastructure (including rapid charge units)
Potential solution for locations where aesthetics are important such
as airports
Type(s) of Innovation
Involved
Technological
Substitution
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
15 -4 19
Expected Benefits of
Project
Benefits are expected to include:
A reduction in street works disruptions
Provision of additional support for the network; the additional
headroom could enable electric vehicle charging points to
connect to the distribution network
The purchase of the urban substation could be partially offset by
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revenue generated from the sale of its advertising space
Expected Timescale to
Adoption 2014
Duration of benefit once
achieved 20 Years
Probability of Success 50%
Project NPV (Present
Benefits – Present
Costs) x Probability of
Success
The major benefits of the
project are its visual
impact, possibly
unlocking new locations
for substations
Potential for Achieving
Expected Benefits
The following areas have been investigated to determine the potential
for the technology to deliver benefits:
Safety considerations
Suitability of the electrical equipment for a UK electricity distribution
network
Additional testing that may be required if the equipment inside the
enclosure is changed
Cost of the substation
Based on the outcome of these investigations, it has been decided not to proceed with a trial installation and the project will close in 2013.
Project Progress
March 2013
Investigations to determine the suitability of the Urban Substation to be installed on the network and deliver benefits to UK Power Networks have been completed. Whilst the unit has a small footprint and was found to be aesthetically pleasing during a display exhibition, it has been decided that the unit is not technically suited for installation to a typical UK Power Networks urban feeder.
The main reasons were:
The differences between the LV fuse types (size, curve, availability)
used in the UK and mainland Europe
The restricted space within the unit meant that standard UK Power
Networks LV panels could not be used in place of the LV panels for
which the unit was originally designed. The option of developing a
modular panel to overcome the space restriction was explored, but
following evaluation, the required investment was not considered
economic
The unit cost was substantially higher than a similarly rated
traditional substation. This is partly due to the supplier’s business
model, and an expectation that the high initial investment cost can
be offset by revenue streams generated from using the advertising
panels on the side of the substation
Concerns were raised in relation to the ease of operational access,
and the substation’s security from malicious or accidental
interference. Whilst modifications could be made to overcome these
deficiencies, they would require significant redesign to the
enclosure before the substation could be deployed without risk
Collaborative Partners N/A
R&D Provider Twelcon
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Strategic Technology Programme (STP) Module 2 – Overhead Networks
Description of Project A DNO research and development collaboration hosted by EA
Technology.
Expenditure for
Financial Year
EPN LPN SPN
External £27,049 £17,339 £17,174
Internal £1,304 £836 £828
Total £28,352 £18,175 £18,002
The costs have been allocated in proportion to the number of customers
connected in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £296,865
Internal £33,760
Total £330,623
Total Project Costs
(Collaborative + External
+ UK Power Networks)
£467,791
Projected 2013/14
costs for UK Power
Networks
External £62,639
Internal £10,000
Total £72,639
Technological Area and
/ or Issue Addressed by
Project
Overhead networks represent both an electrical and a mechanical
system which must provide strength and support in the face of all
foreseeable weather conditions. The module 2 programme looked at a
number of issues with individual overhead components, either of the
line or the structures supporting it, as well as the performance of the
overall overhead line system, such as its current-carrying capacity.
A full list of projects within the programme can be made available on request.
Type(s) of Innovation
Involved
Incremental,
Tech Transfer,
Significant,
Radical
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
16 -9 25
Expected Benefits of
Project
The projects have the potential to deliver a number of benefits:
Reduce levels of premature failure of assets
Increase scientific understanding of processes and climatic
conditions leading to icing
Improve our methodology for determining conductor ratings which
will provide greater confidence
A better understanding of novel conductors for new-build or re-
conductoring lines that gives lower capital cost, minimises visual
impact, and improves environmental acceptance
Expected Timescale to
Adoption
Range 1-5 years –
dependent on project Duration of benefit
once achieved
Range 3-5 years –
dependent on
project
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Probability of Success Range 50-95% –
dependent on project
Project NPV = (PV
Benefits – PV Costs) x
Probability of Success
£40,000
Potential for Achieving
Expected Benefits
Most of the projects are on target for delivering the expected benefits.
This is despite the poor weather during the winter season introducing
some minor delays. For example, the probabilistic wind and ice maps
project is almost complete and the software interface was
demonstrated, giving confidence that the project outcomes were within
reach.
A notable exception is a project to look at further developing the
CORMON system which has failed due to a lack of desire of the
manufacturer to support the work.
A number of projects are progressing according to plan but it is unclear
at this stage whether the outcomes and benefits will be fully. Notably,
project S2126 (conductor temperatures) is delivering very important
information which is contrary to expectations.
Project Progress to
March 2013
Project S2126 (conductor temperatures) is into Stage 7 and it appears that P27 single-circuit ratings are not over-cautious. This has led to work to update the ENA ACE104 Technical Report on overhead line ratings and is expected to have quite a wide ranging impact. Other outputs from this work have been incorporated into the project “Increased Capacity of Overhead Lines”. Projects looking to support residual strength estimations of wood poles and testing new (cheaper) screw anchors for stays are well under way. Initial results for the pole residual strength testing are inconsistent and additional testing is being carried out. The screw anchor testing has given very concerning results over the strength of the anchors, potentially ruling out their wide scale adoption. Further testing is planned to investigate a wider variety of anchor sizes and to compare against traditional block anchors. Other projects such as development of a pole leakage detector (successfully tested at 11kV), and vibration / ice loading tests on fibre wrapped conductors (test line installed, collecting data) are progressing to plan with nothing significant to report.
Collaborative Partners
Scottish Power Energy Networks, Scottish and Southern Energy, Electricity North West, Western Power Distribution, Northern Power Grid
R&D Provider EA Technology Ltd
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Strategic Technology Programme (STP) Module 5 – Networks for Distributed Energy
Resources
Description of Project A DNO research and development collaboration hosted by EA
Technology.
Expenditure for
Financial Year
EPN LPN SPN
External £21,623 £13,861 £13,729
Internal £1,042 £668 £662
Total £22,665 £14,530 £14,391
The costs have been allocated in proportion to the number of customers
connected in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £322,930
Internal £31,687
Total £354,617
Total Project Costs
(Collaborative + External
+ UK Power Networks)
£466,277 Projected 2013/14 costs
for UK Power Networks
External £50,074
Internal £10,000
Total £60,074
Technological Area and
/ or Issue Addressed by
Project
The ‘module 5’ programme aims to facilitate access to low carbon
technologies, ranging from on-shore wind generation connected at
33kV, large distributed generators connected at 132kV and electric
vehicles being charged from the Low Voltage (LV) network.
A full list of projects within the programme can be made available on
request.
Type(s) of Innovation
Involved
Incremental,
Tech Transfer,
Significant,
Radical
Project
Benefits
Rating
Project Residual
Risk
Overall
Project
Score
13.5 -8.5 22
Expected Benefits of
Project
The projects have the potential to deliver a number of benefits:
Investigate distributed generation connection methods avoiding
undue reinforcement
Increased understanding between all member companies on
technical, commercial and regulatory issues and to develop effective
solutions
Developing understanding of the implications of connecting low
carbon technologies to the distribution network in terms of safety,
design, reliability, security and power quality
Expected Timescale to
Adoption
Range 1-3 years
- dependent on
project
Duration of benefit once
achieved
Range 2-5 years –
dependent on
project
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Probability of Success
Range 50-100%
– dependent on
project
Project NPV = (PV Benefits –
PV Costs) x Probability of
Success
£30,000
Potential for Achieving
Expected Benefits
A number of projects are scientific based and will require further
research and development to achieve improvements in operational
performance, and integration into the Network Operators business
environment. Other projects are well developed and provide a clear
view of achievable benefits.
The “Dynamic Ratings” project has developed a simple methodology to
provide enhanced overhead line ratings, and work is in progress to
verify this methodology. This will be followed by a gap analysis to define
a roadmap to adoption, and it is expected that benefits will be delivered
by 2015. Other work is investigating the implementation of dynamic
ratings on primary transformers and other plant.
The fault Level programme of work is also highly likely to deliver
benefits by informing UK Power Networks internal standards around the
management of fault level.
Project Progress to
March 2013
Several projects relating to fault level management have been delivered
this year. They will help to shape our future standards in this area and
ensure a consistent approach amongst all DNO’s. Work included
analysis of the through fault withstand of cables and overhead lines,
and a sensitivity analysis on the effects that network modelling
inaccuracies may have on determining the overall fault performance of
the network.
A project investigating the operation of generation in a voltage control
mode will allow us to connect further generation into areas where
conventional connections are not available due to voltage rise
problems. A solar farm is due to be connected later this year using this
technique which has resulted in a significant reduction in connection
costs when compared to conventional reinforcement. Once proven and
adopted this could create additional capacity for 11kV generation
connections in areas which are already constrained due to existing
generation.
Another project is looking at recommendations for future LV network
design standards to support the connection of new technologies such
as heat pumps and electric vehicle charging points.
Projects looking at network loading including cold load pickup,
standardising definitions of firm capacity, and assessing demand based
on weather conditions will enable a more measured and consistent
approach to Planning Load Estimates and Load indices.
Collaborative Partners
Scottish Power Energy Networks, Scottish and Southern Energy, Electricity North West, Western Power Distribution, Northern Power Grid, NIE and ESB Networks.
R&D Provider EA Technology Ltd
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Transformer Design for FR3 (Completed)
Description of Project
This project is assessing the use of FR3 vegetable oil, manufactured by
Coopers, as an alternative to mineral oil in large power transformers.
FR3 is biodegradable and has a considerably higher flash-point than
mineral oil, however its increased viscosity and oxidisation rate means
that additional design work is needed in the manufacture of the
transformer.
Expenditure for
Financial Year
EPN LPN SPN
External £0 £0 £0
Internal £0 £0 £0
Total £0 £0 £0
The costs have been allocated to the EPN licence area where the
transformer is in service.
Expenditure in Previous
(IFI) Financial Years
External £1,211,147
Internal £114,397
Total £1,325,544
Total Project Costs
(Collaborative + External
+ UK Power Networks)
£1,323,544 Projected 2013/14 costs for
UK Power Networks Project Completed
Technological Area and
/ or Issue Addressed by
Project
The demonstration aims to:
Evaluate the use of FR3 as an environmentally-friendly and safer
alternative to mineral-oil insulation of 132kV transformers
Assess the reaction of the plant components to FR3 and the
comparative ageing of transformers with FR3 versus mineral oil
Type(s) of Innovation
Involved Incremental
Project Benefits
Rating
Project
Residual Risk
Overall Project
Score
11.2 3 8.2
Expected Benefits of
Project
Expected benefits include:
Improved safety for staff and public in the event of failures
Reduced clean-up / disposal costs of insulating oil
Reduced carbon-footprint of operations
Life-extension of transformer insulating paper
Expected Timescale to
Adoption 2014
Duration of benefit once
achieved 20 years
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Probability of Success 75%
Project NPV (Present
Benefits – Present Costs) x
Probability of Success
Small
Potential for Achieving
Expected Benefits
The project has successfully installed and operated a 90MVA FR3-filled
transformer, alongside an identical mineral-oil filled transformer, for over
48 months with no abnormal operation observed.
The UK Power Networks transformer will remain in operation and further
analysis work will be carried out by a Transformer Research Consortium
led by Manchester University.
FR3 will be considered as an alternative to mineral oil by UK Power
Networks as part of the design of a new underground primary
substations expected to be built in the Hyde Park area during the RIIO
ED1 period.
Project Progress
March 2013
The project is now completed and the following conclusions have been drawn:
FR3 has been shown to have a good potential as design changes
to accommodate the oil are relatively straightforward
Results have so far indicated that the FR3 transformer has similar
performance than the mineral oil transformer on the same site. It
has been confirmed that top oil temperature is approximately 5ºC
higher and core temperature around 10ºC higher in the FR3 filled
transformer under similar load due to the viscosity of the medium
The potential long term performance and life-extension
improvements of FR3 needs further research taking into
consideration operational performance
Further work is required to develop asset management
methodologies alongside traditional oil analysis. For example,
industry agreed ranges of dissolved gases and other FR3
characteristics are needed to provide asset engineers with
confidence in evaluating the condition of FR3-filled units
Investigations into the implications for the supply-chain and safety
case have revealed that there would be limited savings from
handling and containment costs in using FR3 under current
regulations. Benefits would therefore be limited to reduced risk of
fire damage and other consequences of failure for FR3-filled units
Collaborative Partners N/A
R&D Provider Areva, University of Manchester, Coopers Power Systems, and Brush
Transformers
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Fault Level Management Study
Description of Project
The project will investigate the potential for modern fault level management technologies and designs to improve network fault levels, and the connection potential of embedded generation where its fault level contribution would currently impact on the generation connection prospects.
Expenditure for
Financial Year EPN LPN SPN
External £0 £4,700 £0
Internal £0 £174 £0
Total £0 £4,874 £0
The costs have been allocated to LPN as the project is primary looking
to address fault level issues and scope a demonstration project in this
licence area.
Expenditure in Previous
(IFI) Financial Years This is a new project for 2012/13.
Total Project Costs
(Collaborative +
External +
UK Power Networks)
£42,799 Projected 2013/14 costs
for UK Power Networks
External £34,499
Internal £2,800
Total £37,299
Technological Area and
/ or Issue Addressed by
Project
Smart technologies to release capacity – management of system fault levels and optimal use of fault level headroom
Type(s) of Innovation
Involved Incremental
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
16.8 -6 22.8
Expected Benefits of
Project
Benefits are expected to include:
Full visibility of costs, benefits, and maturities of modern fault level
management solutions
Network specific modelling of performance of potential solutions
Definition of follow-on projects required in order to deliver
successful fault level management techniques and enabling
significant improvements in generation connection potential
Expected Timescale to
Adoption < 5 years
Duration of benefit once
achieved
Lifetime of assets (>20
years) or enabled
connections
Probability of Success 60% - 80%
Project NPV (Present
Benefits – Present
Costs) x Probability of
Success
£ 100,000
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Potential for Achieving
Expected Benefits
The objective of the study is to produce the knowledge and feasibility
studies required to scope a demonstration project, and to integrate
smart fault level management solutions into UK Power Networks’
practices.
These have the potential to save DG customers the cost of significant
connection-driven network upgrades such as switchgear replacements
driven by fault level.
Project Progress
March 2013
The first report reviewing UK Power Networks modelling and
assessment techniques with respect to system fault level has been
issued. This work has been completed to inform the assessment of fault
level management solutions within the context of UK Power Networks
practices.
A draft second report has been issued. It defines current industry-
leading technologies and management solutions with respect to fault
level, their maturities, and a definition of their development and trial
performances.
The next steps will be to validate the performance and cost of these
solutions, before progressing to selected case study analyses within the
LPN network.
Collaborative Partners N/A
R&D Provider Parsons Brinkerhoff
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Understand Current and Future Performance of the HV and LV Network
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Distribution Network Visibility
Description of Project
The project proposes to develop a solution that will allow UK Power
Networks to evaluate the benefits that can be derived from improved
utilisation of existing data sources Remote Terminal Units (RTUs),
better visualisation of this data and enhanced monitoring of the
distribution network where RTU installation is not plausible, using optical
current sensors.
The project is co-funded with the Low Carbon Networks fund. Benefits
from the project will include supporting Low Carbon Technology uptake,
as well as managing existing network loads and equipment.
The demonstration will be carried out in the LPN area as the population
of RTUs is much greater than in the EPN and SPN areas.
Expenditure for
Financial Year
EPN LPN SPN
External £0 £138,643 £0
Internal £0 £5,143 £0
Total £0 £143,786 £0
The costs have been allocated to LPN as the trial is being carried out in
this licence area.
Expenditure in Previous
(IFI) Financial Years
External £61,366
Internal £5,550
Total £66,916
Total Project Costs
(Collaborative + External
+ UK Power Networks)
£3,085,000
Projected 2013/14
costs for UK Power
Networks
External £440,068
Internal £26,500
Total £466,568
Technological Area and
/ or Issue Addressed by
Project
To develop an innovative monitoring solution:
Increase data collection, upgrade operational data store (data
warehouse – PI), develop visualisations, and improve interaction
between business systems.
Demonstrate the benefits of an improved visibility of power flows:
Maximise utilisation of the distribution network
Accommodate higher levels of distributed generation
Better understand network behaviour: load profiles, power factor and
imbalances
Ability to automatically detect asset defect (e.g. tap changers)
Evaluate a range of non-invasive optical fibre based sensors:
Main features: directional power flows, current, voltage, fault current
measurement
Application: Sites with no RTU (LPN, EPN and SPN areas),
monitoring of complex networks
Type(s) of Innovation
Involved
Incremental,
Significant
Project
Benefits
Rating
Project
Residual Risk
Overall Project
Score
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14.6 -2 16.6
Expected Benefits of
Project
Benefits are expected to include:
Improved switching and load transfers using historical load and
voltage trends
Assist in network reinforcement schemes and particularly with new
customer load connections by providing an overview to planning
engineers in respect of load demands and profiles
Easier planning processes to determine options for load growth and
new load e.g. transfer or upgrade circuits
Improved management of secondary substation ventilation
Validation of existing tap changer maintenance policy leading to
better more cost effective maintenance
Enable a higher penetration of renewable generation
Visualisation of the load on the system, which should lead to
improvements in the rebalancing of circuits following a system
disturbance such as a fault
Expected Timescale to
Adoption 2013
Duration of benefit
once achieved 10 Years
Probability of Success 80%
Project NPV (Present
Benefits – Present
Costs) x Probability of
Success
£831,000
Potential for Achieving
Expected Benefits
The project is currently progressing as planned and a first version of the
distribution network visibility tool has been released to business users.
The project is now entering its final phase and will concentrate on the
demonstration of business benefits and the value of combining data
from various sources and business systems.
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Project Progress
March 2013
Visualisation tool development
A web-based visualisation application has been developed to allow the
display of network monitoring data stored in the PI data historian. The
DNV application has been rolled out to various business users to get
feedback, identify improvements and demonstrate the business
benefits. New servers have been installed at a UK Power Networks data
centre enabling the application to be hosted internally.
Upgrade of RTUs
In line with the plan, 510 RTUs were manually upgraded to collect 10
additional half hourly analogues (including voltage and current on all
three low voltage phases). Remsdaq, the manufacturer of the RTUs,
has developed software to allow the automated upgrade of the
remaining 9,000 secondary RTUs in the LPN network. Testing of the
software has commenced.
GE Distribution Power Flow (DPf) software package trial
A trial of the GE Energy’s DPf software was undertaken on a feeder
group fed from an LPN Primary Substation, utilising monitoring data
from secondary RTUs and PowerSense monitoring devices installed to
HV cables.
The software was successfully demonstrated to control engineers and
an extended trial on the LPN LV interconnected network is now being
planned.
Further Roll Out of PowerSense Advanced Monitoring Units
Following the deployment of PowerSense devices to 5 sites in LPN and
SPN, further deployments of HV and LV advanced monitoring devices
were carried out at an additional 10 sites in LPN. This will help
demonstrate the benefits of the technology for different applications.
Collaborative Partners PPA Energy and Capula Ltd.
R&D Providers Remsdaq Ltd, GE Energy, PowerSense A/S
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LV Remote Control and Automation / Smart Urban LV Network
Description of Project
This project aims to provide a complete solution to monitor and
automate the low voltage network. Retrofit-able load break/fault make
switches for underground link boxes will be developed, as well as fault
break/fault make circuit-breakers (CB) for low voltage panels in
substations.
The scope of the LV Remote Control & Automation IFI project which
developed prototype devices has been significantly extended to cover
the development aspects of the Smart Urban Low Voltage Network
LCNF Tier 1 project (both projects will be run in parallel), and will also
part fund the deployment which will investigate potential quality of
supply benefits. Once both projects are completed, approximately 50%
of the technology development cost would have been funded by UK
Power Networks.
Expenditure for Financial
Year
EPN LPN SPN
External £402,205 £229,172 £262,706
Internal £28,071 £15,994 £18,335
Total £430,276 £245,166 £281,041
The costs have been allocated in proportion to the length of installed LV
cables in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £375,057
Internal £39,566
Total £414,623
Total Project Costs
(Collaborative + External
+ UK Power Networks)
£4,300,000
Projected 2013/14
Costs for UK Power
Networks
External £891,000
Internal £45,000
Total £936,000
Technological Area
and/or Issue Addressed
by Project
Management of the low voltage network
Type(s) of Innovation
Involved Significant
Project
Benefits
Rating
Project Residual
Risk
Overall
Project Score
16.2 -2 18.2
Expected Benefits of
Project
The main benefits expected are as follows:
Improved safety for public and utility engineers by using arc-free
switching technology and novel fault-make switching capability
Remote and rapid restoration of supplies
Reduction of customer minutes lost (CML) and customer
interruptions (CI)
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Better understanding of power flows, network load monitoring
Expected Timescale to
Adoption
2015 / 2013 for CB
only solution
Duration of Benefit
Once Achieved 10 years
Probability of Success 80%
Project NPV (Present
Benefits – Present
Costs) X Probability of
Success
£3,100,000
Potential for Achieving
Expected Benefits
The trial equipment has been installed for approximately 12 months and
has operated as expected.
During this time:
Initial GPRS communication issues were overcome, enabling three
months’ worth of half hourly load monitoring data from each device
on the trial circuits to be collected
LV Control Engineers have gained confidence in using the system
and have reacted to fault passage indications (FPIs) from the circuit
breakers and switches. A section of cable with a suspected transient
fault has been successfully identified
The network has been remotely reconfigured by LV Control
Engineers, providing an interconnection between the trial
substations and a back-feed to facilitate the removal and
replacement of CBs (for maintenance purposes), without the need
for manual reconfiguration of the network
A remote reconfiguration of the network to move the normally open
point from one link box to another and transfer load has been
successfully demonstrated
The progress made in the trial area, and initial demonstration of some of
the expected benefits (incipient fault detection and remote network
reconfiguration) provides confidence that the expected benefits will be
realised.
Project Progress
March 2013
The field trial, consisting of a fully functional system which provides
remote control of circuit breakers at two distribution substations and
switches in one link box, has been extended to include an additional two
link boxes. This gives LV Control Engineers remote switching capability
in all link boxes supplied from the LV circuit between the trial sites.
Incipient Fault Detection
FPIs have been triggered from a transient fault on a circuit fed from one
of the trial link boxes. The LV control centre was automatically alerted as
the system was detecting short duration current peaks (approaching
2000A) on one of the phases. These current peaks have not been of
long enough duration to trip the CB or operate a fuse.
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Figure 16: LV control system FPI indication
The FPI readings (Figure 16) have enabled UK Power Networks
engineers to locate the fault within a short section of cable, and the FPI
readings have been validated by a fault disturbance recorder (see
Figure 17). Work is currently underway to pin-point the exact location of
the fault, and repair it before a supply interruption occurs.
Figure 17: Disturbance recorder verifying FPI indication
Load Monitoring & Network Reconfiguration (also see Highlight section at the start of this report)
Half hourly load monitoring data has been collected and archived,
enabling load profiles to be produced from any of the 39 individual
switches and CBs installed. This has provided a clear picture of how the
trial network is loaded.
By remotely moving a normally open point between the two trial
substations, LV Control Engineers have been able to demonstrate load
transfer from one substation to another.
Industrialised Production Hardware
Development of the production hardware is in the final stages, and
validation testing is underway with promising early results.
Design changes based on feedback from UK Power Networks engineers
have been carried out. The production hardware will be easier to install
and operate than the beta hardware currently in use. Figure 18 below
shows the redesigned, link box control panel, link box switch and circuit
19:32:01.18227/04/13
19:32:01.31327/04/13
1.20 1.21 1.22 1.23 1.24 1.25 1.26 1.27 1.28 1.29Time 131 millisecs (ss)
-600
-400
-200
0
200
400
600
800
1000
1200
AC
Cur
rent
(Aac
)
Maximum Minimum AverageInput Ia (I1) (Transient) 285 -282 -8Input Ib (I2) (Transient) 258 -265 -1Input Ic (I3) (Transient) 1300 -515 8Input In (I4) (Transient) 1100 -634 -2
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breaker respectively.
Figure 18: Redesigned hardware
SCADA System Development
UK Power Networks engineers have been working closely with GE
Energy to define the requirements for a new interactive LV control
SCADA system. This will be implemented in a standalone system of
GE’s PowerOn Fusion.
Development of new symbols and interactive LV diagram is progressing
according to plan. Activities to integrate the SCADA system with the LV
devices via the DNP3 protocol have so far proved successful.
The project is on track to deliver an integrated and scalable LV remote
control and Automation system.
Collaborative Partner TE Connectivity (formerly Tyco)
R&D Provider TE Connectivity (formerly Tyco)
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Strategic Technology Programme (STP) Module 3 – Cable networks
Description of Project A DNO research and development collaboration hosted by EA
Technology.
Expenditure for
Financial Year
EPN LPN SPN
External £32,774 £21,010 £20,810
Internal £1,580 £1,013 £1,003
Total £34,354 £22,023 £21,813
The costs have been allocated in proportion to the number of customers
connected in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £344,561
Internal £34,323
Total £378,884
Total Project Costs
(Collaborative + External
+ UK Power Networks)
£542,974 Projected 2013/14 costs for
UK Power Networks
External £75,900
Internal £10,000
Total £85,900
Technological Area and
/ or Issue Addressed by
Project
The Module 3 programme is investigating a number of issues with
individual cable construction components, such as ducts, sealants, and
materials to backfill cable trenches, as well as methods to verify the
integrity and condition of cable circuits.
A full list of projects within the programme can be made available on
request.
Type(s) of Innovation
Involved
Incremental,
Tech Transfer,
Significant,
Radical
Project Benefits
Rating
Project Residual
Risk
Overall Project
Score
14 -8 22
Expected Benefits of
Project
The projects have the potential to deliver a number of benefits:
A clearer indication of cable condition
Potential reduction in the number of cable faults
Alternatives to current design and installation practices which offer
benefits in lower lifetime cost and higher performance (e.g.
increased ratings)
Reduced design costs
Expected Timescale to
Adoption
Range 1-2 years –
dependent on project
Duration of benefit
once achieved
Range 3-5 years –
dependent on
project
Probability of Success Range 45-100% –
dependent on project
Project NPV = (PV
Benefits – PV Costs) x
Probability of Success
£40,000
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Potential for Achieving
Expected Benefits
All the projects being carried out as part of STP module 3 are
progressing according to plan.
A number of projects involve new technical development such as
trialling techniques for assessing the condition of cables, and will
therefore take some time to come to fruition. Other projects are
investigating better ways of improving the operational performance,
management and reliability of cable networks in terms of minimising the
impact on the environment, and improving the safety of both operators
and the public, in a manner that could be implemented through changes
to engineering policy.
STP 3 has also delivered a number of notable innovations since its
inception, such as the CRATER Cable Ratings calculation software and
the Fluid Filled Cable Design Tools, which both provide a more efficient
and cost effective solution for the design and operation of underground
cable circuits.
Project Progress to
March 2013
A particular highlight this year has been two different studies carried out
into the methods for the offline testing of underground cable circuits,
using different types of test philosophy.
The outputs have been two objective reports which indicate the best
methods which should be used to determine cable condition, both in
service and in the factory prior to delivery. These projects will prompt
further work, but they have provided UK Power Networks with valuable
information on how to specify the test methods required for new cables
to be purchased, and what tests can be done to help determine the
condition and future useful life of existing underground cables.
Collaborative Partners
Scottish Power Energy Networks, Scottish and Southern Energy, Electricity North West, Western Power Distribution and Northern Power Grid
R&D Provider EA Technology Ltd
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Strategic Technology Programme (STP) Module 4 – Substations
Description of Project A DNO research and development collaboration hosted by EA
Technology.
Expenditure for
Financial Year
EPN LPN SPN
External £23,620 £15,142 £14,997
Internal £1,138 £730 £723
Total £24,758 £15,871 £15,720
The costs have been allocated in proportion to the number of customers
connected in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £309,719
Internal £31,027
Total £340,746
Total Project Costs
(Collaborative + External
+ UK Power Networks)
£461,794 Projected 2013/14 costs for UK
Power Networks
External £54,699
Internal £10,000
Total £64,699
Technological Area and
/ or Issue Addressed by
Project
The module 4 programme looks widely across substation plant including
transformers, switchgear and protection equipment. It looks at issues
related to maintaining existing assets, including alternative insulating
oils and means to assess the condition of equipment, as well as looking
at new plant options.
A full list of projects within the programme can be made available on
request.
Type(s) of Innovation
Involved
Incremental,
Tech
Transfer,
Significant,
Radical
Project Benefits
Rating
Project Residual
Risk
Overall Project
Score
16.5 -9.5 26.0
Expected Benefits of
Project
The projects have the potential to deliver a number of benefits:
Optimising safety and environmental requirements for management
of insulating oils and SF6
Technical liaison with international utilities to share new technology
and failure modes
Development of condition-based assessments, or tests, to
determine asset condition
Extended serviceable life of switchgear and transformers
Expected Timescale to
Adoption
Range 1-4 years –
dependent on project
Duration of benefit
once achieved
Range 1-6 years –
dependent on
project
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Probability of Success Range 30-95% –
dependent on project
Project NPV = (PV
Benefits – PV Costs)
x Probability of
Success
£30,000
Potential for Achieving
Expected Benefits
A majority of projects being carried out as part of STP module 4 are
progressing according to plan.
A number of projects have successfully carried out condition analysis on
plant removed from service at end of life. By examining this equipment
in detail, it can be confirmed whether the decisions made to remove it
were correct and, where appropriate, alter policies to extend the life of
similar equipment still in service.
Other projects have been investigating improvement opportunities
surrounding: working methods, the performance and reliability of
substation plant, and plant maintenance regimes, in a manner that
could be implemented through changes to engineering policy.
Project Progress to
March 2013
A highlight within this year’s programme has been the technical
evaluation of AC90 lubricant used by UK Power Networks for circuit
breaker mechanism lubrication.
This will enable circuit breaker maintenance techniques to be modified
to improve reliability of operation, and minimise disruption to customer
supplies caused by failure to trip.
Collaborative Partners
Scottish Power Energy Networks; Scottish and Southern Energy; Electricity North West; Western Power Distribution; Northern Power Grid and ESB Networks
R&D Provider EA Technology Ltd
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High Performance Computing Technologies for Smart Distributed Network Operation (HiPerDNO) (Completed)
Description of Project
The mass deployment of network equipment sensors and
instrumentation, millions of smart meters, small-scale embedded
generation, and responsive load will generate vast amounts of data.
Whilst UK Power Networks has not decided to subscribe to all the data
available from smart meters, it is a worthy research question to
understand whether large quantities of data could be analysed to
identify trends and incipient faults.
So-called cloud and grid computing could enable scalable data mining,
feature extraction, and near to real-time state estimation. These and
other High Performance Computing (HPC) tools and techniques have
been recently developed to cost-effectively solve large scale
computational challenges in areas such as genomics, biomedicine,
particle physics and other major scientific and engineering fields that
require similarly scalable communications, computation and data
analysis.
HiPerDNO is a European Commission funded FP7 ICT Energy STREP
(Specific Targeted Research Projects) project which plans to develop
solutions to address future electricity distribution networks.
Expenditure for
Financial Year
EPN LPN SPN
External £-1,264 £-810 £-802
Internal £1,390 £891 £883
Total £127 £81 £80
The costs have been allocated in proportion to the number of customers
connected in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £339
Internal £10,451
Total £10,790
Total Project Costs
(Collaborative +
External + UK Power
Networks)
£5,100,000 Projected 2013/14 costs for
UK Power Networks Project Completed
Technological Area and
/ or Issue Addressed by
Project
Development and testing of novel high performance computing
information and communications technology for active distribution
networks
Development and testing of data mining features that extract
relevant information
Development and testing of a high-speed messaging layer
Calculation and utilisation of a typical measurement data set for
large amounts of smart meter data in future low and medium
voltage networks
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Customer integration in active network operation
Development and testing of a real-time distribution state estimator
Identification and analysis of new generation DMS functionalities
Development and testing of a new generation network service
restoration algorithm
Development of novel state estimation algorithms for distribution
networks
Type(s) of Innovation
Involved Incremental
Project Benefits
Rating
Project Residual
Risk
Overall Project
Score
8.6 -1 9.6
Expected Benefits of
Project
This research project will develop a new generation of distribution
network management systems that will exploit novel near to real-time
HPC solutions. The solutions are expected to have inherent security
and intelligent communications for smart distribution network operation
and management. Cost effective scalable HPC solutions will be
developed and initially demonstrated for realistic distribution network
data traffic and management scenarios. The demonstrations will be via
off-line field trials involving several distribution network owners and
operators.
Expected Timescale to
Adoption Year 2020
Duration of benefit once
achieved 10 Years
Probability of Success 75%
Project NPV (Present
Benefits – Present
Costs) x Probability of
Success
This project is expected to
deliver benefits in the order
of millions of pounds. As
part of the project the real
value will be calculated.
Potential for Achieving
Expected Benefits
The project has successfully completed its final external review in
March 2013, and received a positive review of the work carried out
during the project.
The project has achieved its objectives and technical goals with
relatively minor deviations.
Project Progress
March 2013
The outcome of the final external review confirmed that good results
were achieved. All the deliverables have been accepted by the
reviewers and the EC (European Commission) project officers. The
deliverables will be available via the project website (www.hiperdno.eu).
The HiPerDNO project has successfully achieved the design, build, and
demonstration of a cost-effective, scalable and secure high
performance computing platform, high-speed messaging system, data
mining methods and new algorithms for network state estimation,
voltage control, and service restoration for distribution networks.
Field trials were conducted by participating DNOs from Spain, Slovenia,
and the UK. The benefits of integrating the high performance computing
platform, high speed messaging layer, data mining methods, and new
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algorithms were successfully demonstrated.
One work package was led by UK Power Networks and looked at the
potential benefits of enhanced ICT and SCADA
monitoring arrangements in relation to condition monitoring of network
assets. Brunel University provided the academic and research
expertise, and UK Power Networks provided condition monitoring data.
The advanced data mining and clustering algorithms that Brunel
University developed as a result of their work, demonstrated that this
approach to data analysis was highly scalable.
Technical reports have been produced for each of the demonstrations.
Collaborative Partner HiPerDNO is an Integrated Project and is supported by the European
Commission under the 7th framework programme. www.hiperdno.eu
R&D Providers
Brunel University
Electricité de France
Elektro Gorenjska (Slovenia)
Fraunhofer- IWES
GTD Spain
IBM Haifa
Indra
Korona
Union Fenosa Group
University of Oxford
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Understand the Condition of Our Assets
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Sustainable Asset Risk and Prioritisation Modelling
Description of Project
UK Power Networks’ asset engineers have been working closely with
EA Technology to further develop its ‘Condition Based Risk
Management’ (CBRM) tool into a more holistic ‘Asset Risk and
Prioritisation’ (ARP) model.
The model provides a step forward with respect to the existing CBRM
functionality by providing the capability to trade-off the financial and
technical consequences of future decisions to replace assets, refurbish
assets or introduce an enhanced maintenance regime. The tool has
also been developed in a way which foresees that it may in future
recognise plant loading as well as condition in the optimisation process.
Expenditure for
Financial Year
EPN LPN SPN
External £31,845 £17,560 £20,196
Internal £47,499 £26,191 £30,125
Total £79,344 £43,751 £50,321
The costs have been allocated in proportion to the number of
substations in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £718,000
Internal £64,935
Total £782,935
Total Project Costs
(Collaborative +
External + UK Power
Networks)
£ 1,243,071 Projected 2013/14 costs for
UK Power Networks
External £250,000
Internal £20,000
Total £270,000
Technological Area and
/ or Issue Addressed by
Project
Modelling the future condition of assets and
replace/refurbish/maintain decisions on individual components
Inconsistency in asset modelling and information gathering
Preparation for an optimisation which might include plant loading as
a parameter
Type(s) of Innovation
Involved Significant
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
20 1 19
Expected Benefits of
Project
Benefits are expected to include:
Greater consistency of asset health data and forecasts
Enhanced trending capability
Improved confidence of long term degradation and early warning of
developing faults
Integration of risk based approach to asset management
Expected Timescale to
Adoption 2014
Duration of benefit once
achieved 10 years
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Probability of Success 65%
Project NPV (Present Benefits
– Present Costs) x Probability
of Success
£4,500,000
Potential for Achieving
Expected Benefits
The data warehouse (which is critical to the success of the project) has become an integral link between several business systems and ARP. More work is on-going to capture additional data (SAP, PowerOn) and improve the accuracy of the ARP models. Data quality will also be reviewed at regular intervals to ensure that the models are accurate.
Project Progress
March 2013
ARP currently represents eight of the major asset groups in our EPN
licence area, eight in our SPN licence area and six in our LPN licence
area.
Below is a summary of the main developments carried out over the past
12 months:
Each model has now been further developed to cover Health,
Criticality and Net Present Value (NPV) analysis
Plant loading has now been included across a number of asset
classes (132/EHV transformers, pressurised cables, EHV
switchgear and OHL conductors)
Using the data warehouse ARP has become linked to the asset
register database and utilises other business systems (fault and
other databases)
Each model has been expanded to fully incorporate the criticality
proposals set by Ofgem in February 2013
SF6 condition monitoring is now an integral condition measure
within ARP defining intervention strategies based upon the
incoming live data
The wood pole models were expanded to incorporate different
ground conditions, leading to a better life expectancy calculation
The next stage in development is to include load and smart intervention
strategies, and to further refine each model’s outputs.
Collaborative Partners N/A
R&D Provider EA Technology Ltd
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Helicopter Mounted Partial Discharge Locator
Description of Project
This project aims to mount a radiometric partial discharge (PD) locator
to a helicopter and automate the analysis of data to allow fast screening
of potential PD defects during normal overhead line patrol flights.
Expenditure for Financial
Year
EPN LPN SPN
External £0 £0 £0
Internal £340 £118 £270
Total £340 £118 £270
The costs have been allocated in proportion to the number of primary
substations in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £58,437
Internal £5,417
Total £63,854
Total Project Costs
(Collaborative + External
+ UK Power Networks)
£64,582 Projected 2013/14 costs for UK
Power Networks
UK Power Networks
is currently
considering whether
to proceed with the
redesign of the
equipment
Technological Area and /
or Issue Addressed by
Project
Improved management of assets: detection of overhead line and
substation equipment defects.
Type(s) of Innovation
Involved Incremental
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
12 -9 21
Expected Benefits of
Project
Benefits are expected to include:
Avoidance of major disruptive incidents
Ability to carry out surveys on sites before major work (switchboard
replacement, major refurbishment, etc.) commences, hence
reducing risk
Overhead line and substation condition assessment
Improved productivity by obviating the requirement to fund separate
flights, as the technology will be used during scheduled patrol flights
Expected Timescale to
Adoption 2013
Duration of benefit once
achieved 10 Years
Probability of Success 75%
Project NPV (Present Benefits –
Present Costs) x Probability of
Success
£470,000
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Potential for Achieving
Expected Benefits
A trial flight in the WPD license area has indicated that the PD locator is able to determine the presence and magnitude of PD on overhead lines and substations. These initial positive results need be validated by further flights and a comparison of the results with ground based PD surveys. A recent change of aircraft used by WPD will require a redesign and retesting of the PD locator mounting equipment. The project partners are currently discussing whether to proceed with the redesign.
Project Progress
March 2013
Following the completion of the trial flight, an assessment of the
software has also been completed.
The software has been shown to detail the location and magnitude of
PD, as well as the speed and flight path of the helicopter, over a number
of substations and overhead lines. Figure 19 below details multiple
flights over a substation, and the PD measurements recorded (location
and direction). Figure 20 shows a single fly over which detailed no PD
measurements.
Figure 19: Flight path and PD measurements over a substation site
Figure 20: Flight path showing no PD recorded over another substation
Collaborative Partners Western Power Distribution and Scottish and Southern Energy
R&D Provider Elimpus
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Develop Commercial Solutions and Products
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Smart Power Distribution
Description of Project
This project, which is partly funded by the Technology Strategy Board
(TSB), builds on learning obtained in the LCNF Tier 2 funded “Low
Carbon London” project in which Active Network Management and
Demand Response activities are being assessed to understand their
suitability as well as the opportunity available for DNOs.
The learning obtained within the Low Carbon London project has
indicated that the existing commercial opportunities for Combined Heat
and Power (CHP) systems, particularly small scale units, limits their
ability to provide ancillary services.
The project description as stated in the abstract from the TSB
submission is as follows: “This Active Virtual Power Plant Combined
Heat and Power proposal will combine commercial aggregation and
active network management, link demand and supply utilizing clusters
of small CHP generators, and integrate both heat and electricity into a
multi-mode energy Virtual Power Plant that will provide the potential for
greater provision of low carbon energy with limited capital investment”.
Expenditure for
Financial Year EPN LPN SPN
External £0 -£12,238 £0
Internal £0 £24,956 £0
Total £0 £12,717 £0
The costs have been allocated to LPN as the project is being carried
out in this licence area.
50% of the UK Power Networks cost is funded by the TSB.
Expenditure in Previous
(IFI) Financial Years This is a new project for 2012/13.
Total Project Costs
(Collaborative +
External + UK Power
Networks)
£ 166,736
Projected 2013/14
costs for UK Power
Networks
External £0
Internal £13,041
Total £13,041
Technological Area and
/ or Issue Addressed by
Project
This project will investigate technical developments required to enable the control functionality needed for CHP systems to participate in VPP activities.
The project will examine the potential realisation of benefits from the many distributed energy resources embedded within the distribution network. These could include network voltage regulation, peak lopping, and load index improvements.
Type(s) of Innovation
Involved Incremental
Project
Benefits
Rating
Project
Residual Risk
Overall Project
Score
9.6 -4 13
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Expected Benefits of
Project
Improved understanding of the technical and commercial requirements
for operating multiple CHP sites as a coordinated ‘virtual power plant’
Expected Timescale to
Adoption < 10 years
Duration of benefit
once achieved 8 Years
Probability of Success 20% - 40%
Project NPV (Present
Benefits – Present
Costs) x Probability of
Success
£284,000
Potential for Achieving
Expected Benefits
Future realisation of the benefits of DNO utilisation of a VPP will depend
upon customers’ widespread use of CHP and control systems that are
fit for this purpose, as well as customer commercial willingness to
deliver sufficient recruitment and participation. These realisations will
become more likely over the second half of the RIIO-ED1 period.
Project Progress
March 2013
The project has developed and issued a report on the Demand Response Requirements of the DNO, completing the first project deliverable. A modelling strategy has been proposed by UK Power Networks and accepted across the project for use in the delivery of the remaining project benefits, using network models to identify specific case study demand response requirements. Finally, the CHP sites making up these case studies have been selected and work has commenced on the final UK Power Networks project deliverable.
Collaborative Partners
Advanced Digital Innovation Limited, Flexitricity Limited, Smarter Grid
Solutions Limited, Ener-G Combined Power Limited
R&D Provider N/A
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Collaborative Programmes
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Energy Innovation Centre
Description of Project
UK Power Networks has joined the Energy Innovation Centre
(http://www.energyinnovationcentre.com/) and has started the following
collaborative projects:
Cable paper moisture meter (1) The project proposes to develop a paper moisture analyser, an instrument that will be used by cable jointers to test the moisture level in paper insulated cables. The problem was first identified under STP3 which sponsored some practical work by EATL to investigate a number of different ways of paper moisture measurement. The work showed that both infrared and capacitive methods of measurement had some merit but the results were not conclusive as the testing was conducted with off the shelf hardware that was not physically suited or calibrated to this particular application. EATL has subsequently conducted further test work exploring the use of multi-frequency measurement as a technique as opposed to the single frequency work previously carried out. Results from this test work were positive. The instrument will allow this operation to be performed more safely than the currently used oil or paraffin solutions. The instrument will produce quantifiable results with a higher level of confidence and will require a shorter time to perform each measurement.
Oilcable-Care (2)
The project seeks to identify, develop and assess self-repairing systems
for oil and fluid filled cable sheaths such that damages will self-heal.
This will avoid oil leakage, the resulting environmental clean-up, as well
as prevent contamination of the cable that could compromise its
performance and lead to premature failure.
Several additional opportunities are currently being considered.
Expenditure for
Financial Year
EPN LPN SPN
External £36,204 £23,209 £22,987
Internal £1,343 £861 £853
Total £37,547 £24,070 £23,840
The costs have been allocated in proportion to the number of customers
connected in each licence area.
The expenditure reported this year only includes the Energy Innovation
Centre annual subscription fee. Project cost will be reported next year
once projects are underway.
Expenditure in Previous
(IFI) Financial Years This is a new project for 2012/13.
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Total Project Costs
(Collaborative +
External + UK Power
Networks)
£ 614,807
Projected 2013/14
costs for UK Power
Networks
External £250,000
Internal £15,000
Total £265,000
Technological Area and
/ or Issue Addressed by
Project
Cable paper moisture meter
Safety of staff
Cable jointing
Underground cable faults
Oilcable-Care
Fluid Filled cable leaks
Environmental impact
Type(s) of Innovation
Involved Significant
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
(1) 15.4 (2) 8.6
(1) -2
(2) 3
(1) 17.4
(2) 5.6
Expected Benefits of
Project
Cable paper moisture meter
Successful completion of the project will result in:
Improved reliability of cable jointing reducing fault re-occurrence
Safer method of assessing the moisture level in cables
Reduced environmental impact through reduced excavation as a
result of fault re-occurrence
Reduced CI and CMLs from more reliable repairs
Oilcable-Care
Indicative data shows that the current cost of this problem is of the
order of several million pounds per annum across the UK. Financial
savings would be achieved from the reduced need to repair cables. The
project is also expected to result in:
Improved reliability of cables
Reduced environmental impact through a reduction in the amount
of oil leaking from cables
Reduced CI and CMLs as a result of more reliable cables
Expected Timescale to
Adoption
(1) 2015
(2) 2017/18 Duration of benefit
once achieved
(1) 10 Years
(2) 25 Years
Probability of Success
(1) 20 - 40%
(2) 40 - 60%
Project NPV
(Present Benefits –
Present Costs) x
Probability of
Success
(1) £505,000
(2) £133,062
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Potential for Achieving
Expected Benefits
Cable paper moisture meter
Although multi frequency measurement has not previously been applied
to this measurement application, there is academic literature which
supports the view that the technology could be successful in this
application.
Additionally, preliminary evaluation work gave some encouraging
results. One of the unknowns is whether it can be successful with the
variety of cables of different ages and from different manufacturers. A
further unknown is the complexity of the final instrument and whether it
can be simple enough to require only minimal training to use, and at a
cost that is acceptable to the DNOs.
Oilcable-Care
EDF R&D has done some previous research work in this area and has
patented an oil additive with self-healing properties. This improves the
potential for achieving the expected benefits.
Project Progress
March 2013
Cable paper moisture meter
The project is expected to start in 2013/14.
Oilcable-Care
The project is expected to start in 2013/14.
Collaborative Partners
Cable paper moisture meter: Electricity Northwest, Scottish Power
Energy Networks
Oilcable-Care: Northern Power Grid and Electricity Northwest
R&D Provider
Cable paper moisture meter: EA Technology Ltd
Oilcable-Care: Gnosys / EDF R&D
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Power Networks Research Academy
Description of Project
The Power Networks Research Academy (PNRA) has been established
through a strategic partnership agreement between the Engineering and
Physical Sciences Research Council (EPSRC), electricity transmission
and distribution companies, and related manufacturers and consultants.
The Academy funds and supports PhD researchers in power industry
related projects and helps maintain and improve the research and
teaching capacity in power engineering subjects.
Expenditure for
Financial Year
EPN LPN SPN
External £17,034 £10,919 £10,815
Internal £632 £405 £401
Total £17,665 £11,324 £11,216
The costs have been allocated in proportion to the number of customers
connected in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £197,638
Internal £27,027
Total £224,665
Total Project Costs
(Collaborative +
External +
UK Power Networks)
£1,915,000 Projected 2013/14 costs for
UK Power Networks
External £21,524
Internal £3,000
Total £24,524
Technological Area and
/ or Issue Addressed by
Project
The projects of most interest to UK Power Networks are:
Overhead lines measurement system
Application of artificial immune system algorithm to distribution
networks
Reactive power dispatch using distributed generation
Alternatives to Sulphur Hexafluoride (SF6) as an insulation medium
for distribution equipment
Further projects related to the distribution and transmission networks
are also being carried out.
Type(s) of Innovation
Involved
Significant,
Technological
substitution and
Radical
innovations
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
9.4 0.0 9.4
Expected Benefits of
Project
Industry, IET and academia have agreed that the projects are beneficial
to both the DNOs (through potential breakthroughs that could lead to
new practices or products) and to academia by raising the profile of
power engineering.
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Expected Timescale to
Adoption
Year 2013
onwards
Duration of benefit once
achieved 20 Years
Probability of Success 25%
Project NPV (Present
Benefits – Present Costs) x
Probability of Success
£200,000
Potential for Achieving
Expected Benefits
Most of the projects are progressing according to plan and are expected
to deliver the expected benefits. Some of the highlights are presented
below:
Overhead lines measurement system
Two laboratory prototypes have been successfully developed.
Application of artificial immune system algorithm to distribution
networks
The benefits have been proven using generic distribution network
models to detect both voltage weak buses, voltage sags and unbalance.
This research is being continued by another researcher within the
Power Quality and Dynamics group (under Prof. Milanovic’s
supervision) at the University of Manchester. All issues have been
written up and documented as part of the PhD thesis associated with
this project.
Reactive power dispatch using distributed generation
Present progress continues to indicate that both power system losses
and voltage profiles can be enhanced with the involvement of DG, as
performed on the IEEE 30 bus system. As such, it is believed that the
expected benefits of the project can be realised.
Alternatives to SF6 as an insulation medium for distribution
equipment
It is still expected that the benefits of this project will be accomplished
as the work continues to progress well. This is backed by the interest
shown by switchgear manufacturers, Schneider Electric, and the
progress that has been made producing a suitable test rig to test the
characteristics of Trifluoroiodomethane (CF3I) alongside the facilities
available at Cardiff University.
Project Progress
March 2013
Only relevant progress for projects of most interest to UK Power
Networks is presented below.
Overhead lines measurement system (completed)
The prototype system was further developed to the point where two
prototypes have been tested and verified in laboratory conditions. The
project is being continued at Cardiff University and field trials are
planned to fully assess the potential of the technology.
Application of artificial immune system algorithm to distribution
networks (completed)
Work on collating all the developed techniques into an overall system
state estimator capable of identifying the worst served and weakest
areas of the network (in terms of Power Quality) has been completed.
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This research has been written up as a thesis, which has been
examined and passed at the University of Manchester.
Reactive power dispatch using distributed generation
A balanced voltage control algorithm has been developed. The algorithm has three significant control actions. Firstly, available reactive power reserves are utilised. Then, if required, DG active power output is curtailed. Finally, curtailment of non-critical site demand is considered. A merit order of selecting DG units to participate in reactive power support is based on the sensitivity of the network to reactive power injection or absorption at the DG unit’s point of connection. In practice the merit order is also envisaged to acknowledge the speed of response of units in the dispatch process. The control algorithm has been modified to control voltages on unbalanced distribution networks, to work with the presence of existing network reactive power support, and for a range of DG units.
Final testing of the control technique is to be carried out on a model of
the Westray network (Orkney Islands, Scotland).
Alternatives to SF6 as an insulation medium for distribution
equipment
The construction of a test rig that utilises switch disconnectors provided
by Schneider Electric has now been completed at Cardiff University.
Fundamental laboratory experiments are being developed to gas, de-
gas and filter the equipment with CF3I and CF3I-CO2 gas mixtures.
Collaborative Partners
EPSRC, The IET and the following industrial partners:
Western Power Distribution, EA Technology Ltd, National Grid and
Scottish and Southern Energy
R&D Providers Universities of Cardiff, Manchester; Queens (Belfast), Southampton,
Strathclyde, and Imperial College London
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Collaborative ENA R&D Programme
Description of Project
The Energy Networks Association (ENA) represents all the UK network
operators. Several projects have been initiated by the ENA R&D
working group and have been funded through the IFI.
Expenditure for Financial
Year
EPN LPN SPN
External £19,731 £12,648 £12,528
Internal £732 £469 £465
Total £20,463 £13,118 £12,992
The costs have been allocated in proportion to the number of
customers connected in each licence area.
Expenditure in Previous
(IFI) Financial Years
External £606,285
Internal £82,226
Total £688,511
Total Project Costs
(Collaborative + External
+
UK Power Networks)
£845,104
Projected 2013/14
Costs for UK Power
Networks
External £100,000
Internal £10,000
Total £110,000
Technological Area
and/or Issue Addressed
by Project
The projects listed below address issues which have been identified by
the ENA working groups as significant – requiring technical
investigation and development.
Harmonic Impedance Modelling
The project addresses the detailed modelling of cable and overhead
line components, to develop cable models appropriate for distribution
networks.
Earthing Project – HV/LV Earthing Transfer
The aim is to develop new techniques to assess the impact of lower
voltage earth electrodes on higher voltage ‘hot zones’ and to measure
the resistance of distribution substation earth systems.
Smart Grid Forum Workstream 3 Phase 1 & 2
The project takes the impact of Britain’s future energy scenarios into
key strategic directions for network development, identifying the needs
for network expansion and the opportunities for smart grid techniques
to drive cost-efficiency and deliver new services. It considers the
enablers for change, including the necessary development of
commercial and regulatory frameworks.
DC Injection
Investigation into the corrosion effects of DC on DNO networks with
specific emphasis on assessing the impact of DC flows in the neutral
conductors.
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Type(s) of Innovation
Involved
Incremental
Innovation
Project
Benefits
Rating
Project Residual
Risk
Overall Project
Score
6.2 -10 16.2
Expected Benefits of
Project
These projects have the potential to provide a wide range of benefits. In
some cases, they will help to understand key asset-related issues and
allow designs to be altered to address them. In other cases they will
allow us to better understand risks to our network, whether from climate
change or changes in demand.
Expected Timescale to
Adoption Year 2012
Duration of Benefit
Once Achieved 10 – 20 Years
Probability of Success 75%
Project NPV (Present
Benefits – Present
Costs) x Probability of
Success
£100,000
Potential for Achieving
Expected Benefits
Work on the harmonic impedance modelling (G5/4) will help DNOs
understand harmonics issues on distributed networks and produce a
revised revision of G5/4. The transfer potential projects will assist with
understanding earthing issues in differing situations.
The remaining projects are still in progress and it is expected that they
will demonstrate the benefits described.
Project Progress
March 2013
Harmonic Impedance Modelling
A final report has been produced and is currently under review. The outputs will be disseminated once it has been approved.
Earthing Project – HV/LV Earthing Transfer
A MS Excel based calculation tool has been developed for analysing the earth fault current distribution for the full range of representative 11kV cables.
An extension to the project to include voltages from 33kV up to 400kV
has been proposed. This new proposal is to add a representative
sample of DNO 33kV, 66kV and 132kV cables into the routines. The
33kV and 66kV circuits and cables have many similarities to those
previously modelled and can be added using the methods already
developed. The 132kV circuits are more complex in terms of cable
construction, circuit configuration, end resistance value (low) and circuit
length (quite long).
Smart Grid Forum Workstream 3 Phase 1, 2 & 3
Phase 2 has developed a technical model and cost benefit analysis
network investment tool for a range of typical network types from EHV
to LV. The model can be run against synthetic networks at each voltage
level under a range of low carbon uptake scenarios. As of March 2013
phase 2 is completed and can now be used for ED1 Business Plans. Work is currently commencing on WS3 Phase 3.
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DC Injection The objectives have been defined and the project is currently progressing through its early stages.
Collaborative Partners
National Grid; Scottish Power Energy Networks; Scottish and Southern
Energy; Electricity North West; Western Power Distribution and
Northern Power Grid
R&D Providers TNEI, EA Technology Ltd (and partners), Earthing Solutions, Intertek
and CAPCIS