Energy Innovation Basecamp - Problem Statements

Problem Statement Title

EIP001 - How can we enable the future Gas Distribution System Operator?

Problem Statement Details

Existing network control centre processes are developed for use with traditional producers/sources including from the NTS & Biomethane. As the energy system transitions to lower carbon gases, a new system control solution needs to be developed to facilitate ease of use across pressure tiers, including accounting for the required flexibility & storage requirements of the future. Future Gas Distribution System Operation will be reliant on collaboration between GDNs & DNOs to enable an efficient and coherent approach to the energy system transition.

Key Stakeholders
GT&M, Producers/Shippers, Market Services (NGN), System Control (NGN), Supply Strategy (NGN), OFGEM, 3iG (NGN)

Target Market
Systems Modelling Providers / AI Developers

Enablers and Constraints
Enablers are considered to be utilising learnings and engagement with the existing National Future System Operator work streams.

Scalability and Target Implementation Date
Any suitable solution would need to be developed in line with NGN Cyber Security requirements, which would be enabled by collaboration with NGN’s 3iG Teams. A prototype solution would need to be modelled and tested on a separated system to enable benchmarking against existing processes to validate accuracy and performance. Once proven an implementation plan is required to facilitate a seamless transition between existing and new systems.

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Problem Statement Title

EIP002 - Can we streamline the wayleaves and consenting process?

Problem Statement Details

We are seeing a large number of requests for connections work associated with the installation of heat pumps and electric vehicle chargers. Our current process for receiving consent to carry out work, such as unlooping of services, follows our standard process for all wayleaves, involving an external agency to contact customers to arrange consents. This adds time and cost to the process. We want to streamline the process and improve data quality and completeness through a digital self-service wayleaves platform.

We would like to develop a digital platform that would allow customers to consent to work on their land and, where required, would allow their neighbours to consent to work being undertaken on adjacent land. This would create a more efficient process reducing time and cost.

In addition, the platform could be used to provide extra information to the DNO in addition that already provided, to further streamline the process. It could also give customers, particularly neighbours, information about the process of unlooping and what any potential work would entail. This would be useful in smoothing conversations that our operatives have on site with householders.

Key Stakeholders
Residential customers will be the key beneficiaries in getting faster LCT connections.  DNOs will benefit from time, resource and cost savings.

Target Market

Our forecasts predict the installation of c. 140,000 EV chargers by the end of RIIO-ED2 (c. 120,000 in SEPD and c. 20,000 in SHEPD). We also forecast c. 120,000 heat pumps will be installed in the same time period (c. 90,000 in SEPD and c. 30,000 in SHEPD). Approximately 1 in 10 installations could require services to be unlooped. We would therefore estimate that we would be looking to use this service between 14,000 and 28,000 times in the next 5 years. The requirement for this service would also continue for the longer term as home continue to decarbonise.

Enablers and Constraints
No enablers or constraints have been noted. However, it must be noted that a digital service will not be able to facilitate consents in all circumstances. The process must allow for other avenues to be pursued if, for example, properties are rented or in the event of neighbour disputes.

Scalability and Target Implementation Date
At a minimum, a successful solution will be able to be applied across the SSEN distribution areas facilitating the connection of up to c. 30,000 LCT devices in the next 5 years. In theory this approach can be adopted by all DNOs and has the potential to facilitate a huge number of connections across Great Britain. It may also be applicable to other nations.

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Problem Statement Title

EIP003 -Can we streamline wayleaves renewals?

Problem Statement Details

Our wayleaves plans and drawings are often kept on file in paper form or have also been scanned and are kept in digital format. While this means that in the event of dispute or other problem, we have the evidence we need to resolve them, it means that the richer data they contain cannot be readily accessed by operational or investment planning teams.

We are looking for a way to release all the data contained in the wayleaves – such as landowner, location, expiry date and any conditions attached to the wayleave – to improve the efficiency of our operations. This will need to be aligned with our existing systems such as GIS, Asset Management and Network Management systems. This will allow the data to be accessed by a number of operational teams. It will also allow for better communication with landowners when assets need to be replaced or refurbished, it will allow any gaps in consents to be identified, and it will allow for a more streamlined approach to wayleave renewal.

Key Stakeholders
DNOs, landowners and agents.

Target Market

This approach will be able to be adopted for all DNOs/ licensees, and will take in all wayleaves held in Great Britain.

Enablers and Constraints
No enablers or constraints have been identified – GDPR/Privacy Issues may be a challenge.

Scalability and Target Implementation Date
This innovative approach can be applied to all DNOs. There is no required implementation date but the sooner it can be implemented the sooner benefits will be accrued.

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Problem Statement Title

EIP005 - How can we collect suitable data for AI assessments?

Problem Statement Details

The use of AI for defect recognition on our above-ground pipework is promising – however, it requires a significant amount of footage to 'teach' the AI, which we do not have to date.

Historically our data is not of the required quality or in the right quantity for AI to be a success, so we need better ways to gather, collect and store this data.

Key Stakeholders
Data, Cyber, Asset, Hydrogen

Target Market

Gas

Enablers and Constraints
Constraints in the past have been that all our historic data has not been of the required quality or quantity. In particular, we struggle with collecting data over a large site area and under above-ground pipelines.

Scalability and Target Implementation Date
RIIO-2, RIIO-3 and onwards.

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Problem Statement Title

EIP009 - Can digitalisation bolster (<2 bar) resilience?

Problem Statement Details

GDNs are continuing to deliver their Digitalisation Strategies, facilitating a greater ability to utilise real-time pressure monitoring and system management through use of distributed technology such as IoT (Internet of Things) enabled devices.

Part of this work should also include evaluating the value of capturing, monitoring and reporting on different metrics. Today, the networks predominantly analyse pressure, flow, temperature and quality (at specific locations). Future networks (< 2 bar) may benefit from the ability to report and react to differing metrics (i.e., composition, calorific value, velocity…). Outcomes of this evaluation will identify a suitable range of device/instrumentation types that could be deployed on the network, the volume required, suitable locations, and how deployment of such devices should be prioritised.

There is an increasing need to understand the requirement and feasibility of providing low power solutions to facilitate installation of such equipment at higher volumes and increased remoteness across the network. This will improve GDNs ability to efficiently manage the gas distribution network today, however, this will also increase resilience and reliability during the energy system transition as a result of changing customer demands.

Key Stakeholders
Other GDNs, DNOs, Local Authorities, Customer Groups

Target Market

Technology Partners, Academia

Enablers and Constraints
Enablers: Existing projects looking at what technology can be deployed onto the network to enable digitalisation.

Scalability and Target Implementation Date

RIIO-GD2 and beyond, dependant on proposals.

Solutions could be scalable across Network Operations, System Control, Network Analysis & Modelling.

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Problem Statement Title
EIP014 - Can we manage tree-cutting activities digitally?

Problem Statement Details
Any tree or other vegetation that is close enough to live overhead power lines could present a safety hazard - either by allowing persons to climb and get too near, or by causing supply disruption if its branches touch or fall onto live lines.

DNOs currently visually inspect overhead lines to ensure no vegetation is within the specified vicinity of overhead lines. Is there an alternative efficient and safe method using novel technology to identify tree species and proximity to overhead lines?

DNO vegetation management programmes are based up the results of inspection data and anticipated tree growth data. Future tree growth rates could be highly variable as our climate changes. We are looking to understand the effect climate change will have on different tree species to provide a predictive model for vegetation growth and therefore provide a better targeted vegetation management programme.

Other aspects of managing tree cutting activities include asset data collection, work planning, pre-cut surveying, post-cut auditing and reporting, and the ability to digitalise these alongside vegetation management would also be beneficial.

Key Stakeholders
Asset/Portfolio and Operations Management teams in all Electricity Network Operators (efficiency of planning and operations), and consumers (improved network performance and reduced unplanned interruptions).

Target Market
This solution can lead to a better targeted vegetation management programme which will improve the safety and reliability of the electricity network particularly in storm conditions.

Enablers and Constraints
Overhead lines are routinely inspected to assess their condition and assessments of vegetation intrusion are made during these inspections.

An app was tested within both SEPD and SHEPD which is currently successfully used as an asset data collection tool. As much as that capability is well supported, the other activities within the end-to-end Tree Cutting process require additional capabilities not supported by CHiME.  Solutions should be GIS-based or have an interface to GIS; and be dispatchable using Network Reference Numbers (NRNs). Solutions that allow for management of survey information, wayleaves/consents, work orders, auditing functions and reporting would be ideal.

Scalability and Target Implementation Date
The solution can be used by all businesses who operate an exposed, overhead network which can be affected by vegetation growth. There is no ‘hard’ implementation date, however, this would ideally be implemented as early into RIIO-ED2 as possible to maximise the benefits.

In the absence of alternative solutions, current practices would continue to be utilised.

Document available to download here.

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Problem Statement Title

EIP024 - Can we streamline generator compliance assessments?

Problem Statement Details

The ESO has an ambition to achieve Zero Carbon Operation by 2025.The UK government has set out its ambition to deliver 50 GW of offshore wind by 2030. To achieve these targets, high penetration of Inverter Based Resources (IBR) is expected to be connected to the system. When new generators are to be connected to the system, to comply with the grid code, detailed system studies – such as system oscillation studies and control interaction studies – need to be carried out by users/developers. To carry out these studies, the ESO provides network models for the agreed scenarios. The main challenge for the ESO to provide these network models is the difficulty in sharing already-connected generators’ models, due to confidential data issues. In the current arrangement, the ESO will obtain a Non-Disclosure Agreement (NDA) with all parties involved. This process is very time-consuming and in some cases users/developers need to carry out analysis with some generic models.

The aims of this project are:

• to develop a platform where the ESO can publish the network for users/developers to carry out system studies, without providing other users’ confidential data,
• to reduce the time spent on NDA agreements to share third party models, and hence to reduce the cost of connection, and
• to reduce the use of generic models to carry out compliance studies for new connections that will reduce the number of iterations required for model validation.

In addition to the new connections, the developed platform can also provide possibilities to share models to consultants, and academics without sharing any confidential data.

Australian Energy Market Operator (AEMO) developed a Connection Simulation Tool for the same purpose.

Key Stakeholders
Transmission Owners (TOs), Offshore Transmission Owners (OFTO), Generators, Developers

Target Market

New connecting generators, TOs, new technology development.

Enablers and Constraints

Constraints: due to the confidential data and Intellectual Property (IP) details, there are difficulties in sharing the models to third parties. With the existing Grid Codes, the ESO can get models from all generators but may not be able to share these models with third parties. In the current process, the ESO will agree an NDA agreement with all parties involved to share the models to third parties. This is a very time-consuming process that could impact the users’/developers’ project timelines and could increase the cost of delivery.

Enablers: this project aims to develop a platform/portal where NGESO can provide the required models for third parties without sharing the confidential data. This will allow users/developers to carry out all compliance analysis in a timely manner that could reduce the connection delivery cost and the system security risks.

Scalability and Target Implementation Date

The development of a platform where the ESO can publish a network model without sharing confidential data is expected to take 2 to 2.5 years. The platform/portal should have the capability for multiple users, connecting to different part of the system, able to carry out system analysis.

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Problem Statement Title

EIP050 - Remote monitoring of copper cable

Problem Statement Details

Copper buried within Transmission substations that are located under earthing mats can suffer from degradation over time. For general maintenance and overall safety, it is important that we can have efficient methods of assessing the integrity of this material. However, its general location and environment can often be challenging to access. Not only that, the remote locations of SSEN Transmission substations can also add significant operational challenges.

To alleviate these challenges, we are seeking new methods that can enable the safe and effective assessment of copper integrity through remote monitoring solutions.

Key Stakeholders
Network operators, renewable generators, local communities, energy consumers.

Target Market

The intended solution(s) have the potential to have applications across all electricity network operators.

Scalability and Target Implementation Date

For safety criticality and overall operational efficiencies, new solutions and methods are needed right away to prevent further delays on future projects. As a result, there is significant interest in identifying new innovative solutions that have the potential to be deployed in the RIIO-T2 period. This essentially drives the requirement for higher TRL solutions; however, we will not limit ourselves to opportunities that may require further research with a protracted implementation time.

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Problem Statement Title

EIP060 - Can we remotely differentiate leaked and vented gas?

Problem Statement Details

WWU have around 17,600 gas sites of various sizes and ages. These sites reduce gas pressures as gas is transported through the gas network. Pneumatically driven components vent gas as part of normal operation, and safety devices vent gas to avoid over-pressurisation. Gas leaks from the system are predominantly through joints and points of failure. Unless the leaks are large and obvious, these could remain undetected (until the next maintenance/inspection visit) and indistinguishable from gas which is vented. Many of these components alongside others are situated within a housing. As such, solutions must be suitable for indoor operation and ATEX compliant.

We cannot currently detect, quantify and distinguish between a gas leak and gas that is automatically vented without physically going to site and taking manual measurements. The advantage of remote detection means that monitoring can be conducted over a sufficiently long period and multiple sites can be monitored at once. Ideally, the solution is portable so that once a site has met a satisfactory emissions level, the equipment can be transferred to another site for monitoring.

If successful, operational managers would be able to effectively plan for the most appropriate emissions reduction solutions, avoiding over-engineered designs by knowing the location and scale of emissions sources, thus saving gas consumer money and improving public health through better air quality.

Key Stakeholders
Gas consumers, Gas shippers, Gas Distribution Networks, Gas Transmission Networks, Ofgem, BEIS, Manufacturers.

Target Market

The UK signed up to the Global Methane Pledge at COP26 which aims to reduce methane emissions by at least 30% below 2020 levels by 2030. The UK also committed to working to continuously improve the accuracy, transparency, consistency, comparability and completeness of national greenhouse gas inventory reporting.

Enablers and Constraints 

Enablers:

• Cadent’s SIF funded ‘Digital Platform for Leakage Analytics’ project in collaboration with NGG, WWU, SGN and NGN: https://smarter.energynetworks.org/projects/cad_sif0002/
• NGG’s NIA funded ‘Monitoring of Realtime Fugitive Emissions (MoRFE)’ project: https://smarter.energynetworks.org/projects/nia_nggt0137/

Constraints:

• The solution must operate within a hazardous area.
• The greatest challenge will be distinguishing between leaked gas and vented gas.
• Gas emissions quantification is needed, not just detection.
• Considerations need to be given to the compatibility or adaptability to work with future gas compositions (e.g., blended hydrogen/natural gas, full hydrogen).
• Cost-effective for scalability.

Scalability and Target Implementation Date

The project would start by trialling at different sized sites as a proof-of-concept exercise and to confirm whether different solutions are needed depending on the size and type of site. If successful, this can then be rolled out to further sites. The target implementation date would be February 2024 so that gas networks can put forward the solution, alongside supporting evidence, in their RIIO-3 business plans for implementation in 2026-2031.

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Problem Statement Title

EIP025 - What are the market signals for the electrification of heat?

Problem Statement Details

We expect electricity demand from heating to increase drastically from the late 2020s to meet our net zero targets, and have assumed a certain level of flexible consumption across ESO scenarios to minimise system costs (generation capacity, network reinforcement, SO services). It is unclear if the current market design (wholesale, policy support, SO services) is sufficient to enable this transition while managing network/system costs. This project will investigate what market signals (both investment and dispatch signals; from ESO, and wider markets such as wholesale, carbon, DSOs) and enablers (regulations and standardisation etc.) are required to incentivise energy customers to switch to electric heating technologies, adopt flexibility enabling technologies (smart controls etc.) and consume flexibility.

Key Stakeholders
ESOs Future Markets teams, DNOs, electric heating and enabling technology providers, BEIS policy teams, aggregators, suppliers.

Target Market
Enabling GB’s net zero targets, including the 600,000 heat pumps target by 2028. This is likely to be a research-based project to investigate market signal and enablers and will include engagement with energy customers/potential customers.

Enablers and Constraints
Enabler: this project will build on existing understanding of technical capabilities of heating technologies, consumer heat demand profiles, and consumer response to different propositions.

Scalability and Target Implementation Date
The project should recommend changes to existing ESO (DSO) market designs to provide investment and operational signals for electric heating, which should be assessed and adopted by the ESO current service reform process (DSOs).

Document available to download here.

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Problem Statement Title
EIP026 - What will the hydrogen market look like?

Problem Statement Details

How the hydrogen marketplace works in future scenarios (during the transition and onwards) is in development - this challenge should look to bring a consortium together to better determine the optimal approach and the relevant innovations required, i.e., Guarantee of Origin management.

Key Stakeholders
Hydrogen, System Operator

Target Market
Gas and System Operators e.g., ESO

Enablers and Constraints
NIA_NGGT0184 - Gas and Electricity Transmission Infrastructure Outlook:
https://smarter.energynetworks.org/projects/nia_nggt0184/

Scalability and Target Implementation Date
RIIO-3 and onwards

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Problem Statement Title
EIP039 - Can we more accurately model electricity storage?

Problem Statement Details
Electricity storage can play an important role as enabler of renewable energy penetration and facilitate the transition to Net Zero. However, uncertainty in terms of how the assets will operate tends to result in a cautious approach being adopted as part of the connections assessments across Transmission and Distribution Networks. On the transmission network, connection dates being provided to electricity storage developers are far into the future (late 2030s), as a result of the assumptions being used in the studies and the volume of future contracted generation.

We are looking at new ways of modelling electricity storage that better reflect how they intend to operate. This includes exploring the possibility of offering electricity storage an earlier connection onto the network, on the basis that they can be curtailed to zero output at the times of network congestion if they were going to be contributing to the constraints at the time.

The aim of the innovation project is to improve the understanding of the operation of energy storage assets and could cover the following areas:

• How assets of different fuel types operate when co-located with storage e.g., PV and/or wind and storage.
• How the assets operate when providing energy arbitrage and what factors determine when the storage assets would charge or discharge.

This could be achieved by looking at existing operational data for storage assets but also at future data collected once new storage projects are connected on the both the transmission and distribution networks.
The data will enable improved modelling of storage systems which will support long term network planning and development as well as real time operation of the network.

Key Stakeholders
ESO – Network Operability team, TOs, DNOs, electricity storage developers and optimisers.

Target Market
Electricity storage developers.

Enablers and Constraints

Enablers – sharing knowledge and Collaboration with Transmission & Distribution companies and electricity storage developers; sharing of operational data from existing electricity storage units.
Constraints – The lack of clear data and lack of coherent approach of modelling storage across Transmission and Distribution.

Scalability and Target Implementation Date
The modelling approach could be applied across both Transmission and Distribution for all electricity storage.

Document available to download here

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Problem Statement Title

EIP040 - How can we introduce flexibility to distribution networks?

Problem Statement Details
The electricity network in the UK is experiencing significant changes in the way energy is generated and consumed due to the growing integration of LCTs. The UK government’s intention to electrify the transportation and heating sectors have resulted in an increase in network demand, despite improvements in energy efficiency. The growing connection of distributed generation (DG) is also causing an additional strain on the distribution networks from LV (400 V) to HV (11 kV, 33 kV) and EHV (132 kV).

Key Stakeholders
Electricity customers, UK Distribution Network Operators, Grid Assets manufacturers, Ofgem, Network Service Providers, academics and research centres.

Target Market
The Electricity Networks industry is a multi-billion-pound industry (set to have over £20bn investment only during ED2 price control). Market opportunity for rolling out effective solutions that can be competed with conventional reinforcement is significant in this wide market.

Enablers and Constraints
Enablers:

Scalability and Target Implementation Date
The scale of the problem covers all DNOs, and we aim to reduce the scale of this challenge through the ED2 price control period and beyond.

 Full document available to download here.

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Problem Statement Title
EIP041 - Can we accelerate development of co-located storage assets?

Problem Statement Details
Grid scale storage assets have the potential to smooth generation, but also provide flexible demand with long and short duration batteries using same connections. However, these assets tend to compete for connection capacity because there is no incentive to collaborate. There is real need to define flexibility for markets as an enabler or restoration services as a secondary enabler.

Networks and grid service developers need to be incentivised to optimise the development site and maximise the use of land to provide grid services.

Key Stakeholders
NGESO, TOs, DNOs, electricity storage developers and optimisers, electricity generators, site owners.

Target Market
NGESO, Ofgem.

Enablers and Constraints
Enablers – REMA addresses some of this problem (e.g., operability, long duration storage and long duration flexibility, balancing mechanisms) so perhaps needs a local angle or a specific focus such as hydrogen?

Constraints – National Grid tend not to recognise the value provided by co-located assets. They ask who owns assets/connections.

Scalability and Target Implementation Date
In line with REMA review.

Seed Question
Are there any low regrets or quick winds actions ahead of REMA delivering the proposed reforms?

Document available to download here.

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Problem Statement Title

EIP042 - Can grid service equipment better serve onshore substations?

Problem Statement Details

The current Offshore Transmission Owner (OFTO) regime is a barrier to Windfarm Developers connecting equipment to provide Grid Services at the Windfarm’s onshore substation. The OFTO regime drives the minimum cost connection and, at transfer of the windfarm connection assets to the OFTO, a Windfarm Developer would not be reimbursed for any equipment that is installed that is not essential to transmit the Windfarm’s power to shore.

Co-location of Grid Service equipment such as synchronous condensers and energy storage at windfarm onshore substations would help address some of the issues currently faced with the introduction of renewables such as reduced Grid inertia, reducing short circuit levels and intermittency. Building this additional infrastructure at the same time as the windfarm connection would be more cost effective than the build being an independent project with a separate Grid connection.

Potential Solutions are to allow the Grid services equipment to use the OFTO asset for connection and allow it to be retained by the Windfarm Developer or to allow the additional infrastructure to be sold as part of the OFTO asset (with the Windfarm Developer being fully reimbursed) and the Grid services equipment operated by the OFTO providing them with additional revenue.

Target Market
National Grid ESO

Enablers and Constraints
Current OFTO regime

Scalability and Target Implementation Date
Can be implemented as part of the drive for 50GW of offshore wind by 2030.

Seed Question
What are the drivers in favour of maintaining a separate grid connection for additional grid service equipment?

Full document available to download here.

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Problem Statement Title

EIP043 - Is randomised delay in smart chargers a long-term solution?

Problem Statement Details
Currently the solution to managing grid instability from use of smart chargers is randomised delay over a 10-minute period. However, when charging demand is higher (in the future), we will need another (innovative) solution which ensures:

Key Stakeholders
Suppliers, Networks, ChargePoint owners & operators.

Target Market
DNOs, chargepoint owners & operators.

Enablers and Constraints
Enablers – Australia use a dynamic operating envelope, wherein the vehicle is plugged in and the capacity available dynamically on the network is then made available for vehicle charging.

Seed question
Do we know how consumer charging behaviours will respond to various candidate solutions for replacing randomised delay?

Full document available to download here.

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Problem Statement Title

EIP044 - Can we simplify tendering flex products to DNOs?

Problem Statement Details
There is currently no indicator (or poor indicators), of when flexibility services are coming online. A heat map will be made available to indicate where flexibility services will be available in six months with 100% certainty. However, to build flexibility markets with confidence, it may be better to have – for example – 90% certainty of having flexibility services inside three years. Retailers need more flexibility services faster

Key Stakeholders
DNOs, ENA, INA, EIC, Ofgem.

Target Market
DNOs, Ofgem.

Enablers and Constraints
Existing Network innovation projects such as Transpower and Optimise Prime may help accelerate flexibility growth. Secondary generation of non-firm connections on DNO networks may increase the appetite to participate.

Scalability and Target Implementation Date
The scalability pathway should align to National Grid’s FES 2022 (or appropriate DFES) for projected increase in flexibility services and demand side response.

Seed Question
To what extent would regulation and standardisation be required to ensure networks report timescales with repeatability and reproducibility?

 Document available to download here.

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Problem Statement Title

EIP045 - Can we accelerate connections for offshore wind?

Problem Statement Details
At present, offshore windfarms can be built faster than TOs can connect them, and the connections are perceived as high-risk investments before the windfarms are fully developed.

Can we mitigate those risks, unblock and speed up the connections process?

Key Stakeholders
Offshore windfarm developers, Energy Generators, Crown Estate, All networks – primarily TOs

Target Market
Offshore windfarm site owners, onshore asset site owners, Crown Estate & Crown Estate Scotland, Ofgem.

Enablers and Constraints
Enablers:

Problem Statement Title

EIP046 - Can consumer devices provide DNOs with voltage support?

Problem Statement Details
V2G is being held back by voltage issues because the regime pushes out too much power under certain conditions. Pushing power back up the network towards the grid increases the voltage; this is further exacerbated if lots of people do this in the same way at same time.
Due to the induced voltage issues, customers are unable to get connections for V2G.

Key Stakeholders
Customers (domestic and commercial), Networks, Retailers.

Target Market
Early adopter prosumers (domestic and commercial).

Enablers and Constraints
Wholesale price and retail price are very different e.g., retail price has low carbon levies etc., which wholesale does not.

Scalability and Target Implementation Date
The European Combined Charging System for EVs is due to upgrade in 2025, enabling V2G services for many consumers turned prosumers. The scalability pathway should align to National Grid’s FES 2022 (or appropriate DFES) for projected increase in EV uptake.

Seed Question
To what extent do we feel preparing for V2G at grid level will incentivise car manufacturers to move towards V2G eariler and in large volumes?

Document available to download here.

Problem Statement Title
EIP047 - What is the future of energy storage balancing?

Problem Statement Details
Market participants that would like to operate limited storage assets are using workarounds involving manipulating data to inform the control room of their capability. This data manipulation does not fully consider the limited nature of their energy capacity and is more aligned to traditional thermal units. This means that these participants are often under-utilised or requested to provide services that are simply not possible. For the same reasons, connecting new assets to the wider grid can be seen as an unnecessarily complex process considering their flexibility and capability. How can storage units be onboarded and utilised based on both their true limitation and flexibility, and not be treated like a conventional unit?

Key Stakeholders
ESO’s control room engineers, balancing mechanism (BM) and OBP (future Open Balancing Platform) teams, and storage asset operators.

Target Market
Enabling GB’s net zero targets, expected uplift in both the number of storage assets and their capacity over the coming years.

Enablers and Constraints
Enabler - This challenge will build on existing understanding of the technical capabilities of storage technologies and operational information for these. There is a storage stakeholder group recently established by the ESO to discuss and start defining storage capabilities, which this challenge will complement.

Scalability and Target Implementation Date
Projects addressing this challenge could recommend changes to existing ESO market designs for usage of storage assets.
 
Document available to download here

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Problem Statement Title

EIP004 - What does the future Operator Console look like?

Problem Statement Details

The ESO control room manages multiple complex data sources across several tools with minimal use of automation, therefore requiring significant user interactions to maintain system operation. As the complexity of operating the whole energy system grows, the pressure on operators to maintain secure and economic operation of the system increases. We would like to explore how to deliver a high level of situational awareness into the future Control Room, considering human factors associated with UX/UI design and control room operations, including operator interactions with complex data flows and intelligent tools for system operation.

Key Stakeholders
ESO – various teams across National Control.

Target Market

At this stage, we are looking at a research project to understand the different elements of a future operator console, but we are looking to engage with a wide range of suppliers to build a future proof of concept.

Performance and efficiency of the ESO Control Room operations will ensure better decision making, ultimately resulting in lower costs for consumers and progression towards zero-carbon operation.

Enablers and Constraints
Enabler: Operator Console is a deliverable as part of the ESO’s RIIO-2 Business Plan, however we would like to explore beyond this, to ensure the future control room and operator console beyond this time frame are industry leading, to improve system operation.

Scalability and Target Implementation Date
We would like to further inform the Control Room of the future and build in some key principles for situational awareness and human factors. We foresee that this challenge area may result in multiple projects exploring different avenues of these topics in relation to control room operations.

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Problem Statement Title
EIP022 - Can we marry network monitoring and management?

Problem Statement Details
There are several commercially available LV and HV monitoring equipment/solutions which provide impedance-to-fault values for either pre-fault or post-fault events on distribution networks. Converting these impedance-to-fault values to physical locations on networks (e.g., X metres along feeder Y) is typically a manual process which involves support teams carrying out some network modelling or reviewing GIS records to identify cable and overhead line types and characteristics.

In addition to identifying the above, there is a manual process in informing Network Control Engineers and field crews of these pre-fault/post-fault locations - see Figure 1 and Figure 2 on PDF.

Key Stakeholders
Network Control – The solution will enable automated notification to Network Control Engineers and allow them to carry out timely switching on the network to isolate faulting/faulted network sections.

Network Operations – The solution will enable field crews to find the actual location of faults more quickly (for post-fault events) and carry out pre-emptive repairs for pre-fault events.

Asset Management – The solution will remove the need for dedicated roles to carry out the annual tasks associated with identifying pre-fault/post-fault locations and notifying stakeholders. It would also remove the need (and associated costs) for third parties to provide these services.

Target Market
This solution will provide most value for managing LV and HV faults. By either acting pre-fault or locating and responding to post-fault events quicker, customers will see a direct benefit through a reduction in CIs and CMLs.

Enablers and Constraints

• The solution must be technology agnostic, i.e., take impedance to fault values as input from sensors and monitoring solutions from many suppliers in order to provide a location.
• Examples of innovation projects that provide fault locations include but are not limited to: HV Feeder monitoring to pre-empt faults, MILES and Arc Aid.
• The output of the solution must integrate with our current Network Management System, GE PowerOn/ADMS.
• Comprehensive records of LV and HV cables and overhead line conductors are required to calculate pre/post fault locations.
• A key enabler is fully digitised network records (particularly for LV and HV cables and overhead lines).

Scalability and Target Implementation Date
The target date for successful implementation is mid-2024. The solution could be scalable to other DNOs if they have the pre-requisites:

• Commercially available monitoring solutions that provide impedance-to fault values as outputs.
• Fully digitised network records (particularly for LV and HV cables and overhead lines).
• Comprehensive records of LV and HV cables and overhead line conductors.
• Network Management Systems with enhancement capabilities. 

Document available to download here.

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Problem Statement Title
EIP033 - Can material technologies assist the hydrogen transition?

Problem Statement Details
Can we utilise novel materials technologies (e.g., coatings) to reduce the likelihood of ignition of hydrogen following a gas escape? Can the internal surface of assets be engineered (or retrofitted) to reduce hydrogen adsorption? Is there a way to utilise the Salvinia effect, i.e., hairs that prevent hydrogen from reaching steel surface by forming a trapped barrier layer of gas?

Key Stakeholders
Hydrogen, Operations, Construction

Target Market
Gas

Enablers and Constraints
No previous projects in this area

Scalability and Target Implementation Date
RIIO-3 and onwards

Document available to download here

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Problem Statement Title
EIP034 - Can we trial hydrogen assets without using hydrogen?

Problem Statement Details
Testing and trialling gas transmission assets, techniques and new equipment will require large quantities of both hydrogen and natural gas to complete, at a time when demand is high for bottled hydrogen. This can lead to higher prices for demonstration activities and ultimately projects not being funded. An alternative method for carrying out the tests is needed without using hydrogen, and with a reliance on the results and data at the end.

Key Stakeholders
Hydrogen, Operations, Construction

Target Market
Gas, Nuclear, Construction, Automotive, Aerospace, Maritime…

Enablers and Constraints
No previous projects in this area.

Scalability and Target Implementation Date
RIIO-2, RIIO-3 and onwards.

Document available to download here

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Problem Statement Title
EIP035 - How can we prepare operational teams to utilise hydrogen?

Problem Statement Details
Ensuring our operational teams can work with hydrogen is vital to any deployment in the future.

This programme of work will look to ensure all our working practices today can be updated for our Net Zero future. Projects and demonstrations will be needed to provide safety case evidence that our operational practices today can be carried out safely in a blended-or-100% hydrogen scenario. Without this evidence we will not be able to operate a transmission system in the future.

Additionally, our staff - who are proficient with the operation and construction of natural gas pipelines - will need to be trained in how hydrogen will change their jobs and processes. We will need people to quickly become trained and qualified on working around hydrogen.

Hence, we need:

1. Evidence that our working practices can be updated for a hydrogen future
2. Innovative ways to provide training alongside the new material.

Key Stakeholders
Operations, Policy, Hydrogen Teams, Construction, HR

Target Market
Gas Transmission

Enablers and Constraints
NGGTGN04 HyNTS FutureGrid Phase 1 – Transmission Test Facility NIC:
https://smarter.energynetworks.org/projects/nggtgn04/

Scalability and Target Implementation Date
RIIO-2, RIIO-3, and onwards.

Document available to download here

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Problem Statement Title
EIP037 - How can we optimise future asset reliability?

Problem Statement Details
Electricity Network Owners require physical access to their assets to deliver critical asset maintenance and interventions, and enable new, transformative, decarbonised infrastructure and grid connections. This is achieved through the planned outages submitted to and approved by the NGESO. However, outages are becoming more difficult to secure, due to:

• More connections and more critical connections to enable a decarbonised grid,
• Greater demand (due to electrification of transportation and heating),
• Greater intermittent (renewable) generation,
• Greater necessity for network availability, security and reliability, and
• Demand side response (DSR) increasing unpredictability of network availability and, subsequently, outage planning capability.

Failure to deliver critical asset maintenance and new infrastructure has impacts on:

• Safety – failure to maintain asset health can lead to many different (type and severity) risks, ranging from compliance to catastrophic events of asset failure, which cause harm to people (e.g., site engineering, general public) and damage to valuable, critical assets/network.
• Network Reliability – inability to manage network assets decreases the asset and overall network reliability due to higher probability of asset degradation and condition.
• Facilitating and connecting new generation, demand, and infrastructure – not delivering the critical new connections & infrastructure will reduce the rate at which Great Britain can achieve Net Zero and the subsequent greater network flexibility.

Key Stakeholders

Beneficiaries – Electricity Network Owners & Asset Managers (e.g., Transmission Owners, Offshore Transmission Owners); enable electricity infrastructure owners to effectively, affordably (for consumers) manage respective asset bases.

Partners/Third Parties – This challenge aims to enable the management and planning of the GB Electricity Network assets whilst delivering strategic network development and transformation. Therefore, this challenge may have interactions with industry-wide/national strategic network planning activities, such as Network Planning Review (NPR) being led by the ESO, and the Electricity Transmission Network Planning Review (ETNPR) being led by Ofgem.

Target Market
GB Electricity Network Owners – This challenge aims to enable all GB electricity network owners i.e., TOs, DNOs, OFTOs… (with potential application to gas networks/other utilities) to optimally deliver asset management interventions whilst maintaining high reliability and security of supply and delivering major infrastructure and connections.

Enablers and Constraints
Existing innovation project; NGESO: The Virtual Energy System (an NGESO SIF-funded project) aims to create a virtual model of the UK Energy Infrastructure for forecasting, scenario planning and constraint analysis. This tool would be valuable for the assessment of outage scenarios and the capacity for planned outages on the continuously developing network.

Scalability and Target Implementation Date
Target implementation date: prior to 2030, to align to major UK infrastructure transformational targets, including the electrification of transport and heat, and major change to the GB Energy Mix (e.g., 50 GW 2030 East-Coast offshore wind generation target). This would enable electricity network asset owners to (safely and optimally) plan and deliver asset management and new infrastructure works alongside the energy transition.

Document available to download here

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Problem Statement Title
EIP038 - Can we build climate change into power system modelling?

Problem Statement Details
Over the last 5-10 years there has been substantial growth in the capacity of wind and solar generation. In addition, large changes in electricity demand are expected from electrification of heat and transport. This is leading to a growing sensitivity of supply and demand to meteorological conditions. Consequently, to model the behaviour of the power system detailed, meteorological data is required.

At short lead times (< 2 weeks ahead), meteorological data is provided by the latest weather forecast, but at longer lead times there is reliance on historic weather data. However, the climate is changing and there are concerns that the historic data is not representative of the future conditions, particularly at longer time horizons. There is a need to identify the best available meteorological data to model the power system at different time horizons.

Key Stakeholders
ESO FES and Electricity Market Reform teams, DNOs, BEIS, meteorological data providers

Target Market
ESO FES and Electricity Market Reform teams, DNOs, BEIS.
At this stage we are looking at this being a research project to include review and analysis of the available data to identify the source that best meet our needs.

Enablers and Constraints
Enabler – Mapping the impacts and visualization of risks of extreme weather on system operation (MIVOR) https://smarter.energynetworks.org/projects/nia_ngso0023/

Other enablers include the Adverse Weather Scenarios for future electricity systems: long duration events project led by the Met Office.

https://nic.org.uk/studies-reports/national-infrastructure-assessment-old/adverse-weather-scenarios-for-future-electricity-system-long-duration-events/

Scalability and Target Implementation Date
Any Critical National Infrastructure providers (GB and global)

Document available to download here

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Problem Statement Title
EIP056 - Can gas blends be personally detected?

Problem Statement Details
Hydrogen and hydrogen blends have different flammable ranges to natural gas. To enable operatives to appropriately detect leaks and carry out engineering operations such as purging, appropriate gas detection is needed.

Key Stakeholders
Gas network engineers, gas detection OEMs, sensor OEMs

Target Market
Gas network

Enablers and Constraints
Constraints: Currently gas composition is only measured at the national offtake sites.

Scalability and Target Implementation Date
If an appropriate solution is found this can be scaled to use across all gas networks.

Document available to download here

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Problem Statement Title
EIP059 - How can we assure the quality of hidden pipework?

Problem Statement Details
The proposed hydrogen village trial will see current natural gas infrastructure repurposed for hydrogen service, particularly downstream of the gas distribution network, in people’s homes and businesses. The process of conversion will require inspection into the condition of existing assets to ensure they are suitable for repurposing to carry hydrogen.

Current practice in domestic properties with natural gas is to carry out a visual inspection of the pipework that is visible/accessible followed by a tightness test to ensure there are no leaks. Elevated pressure testing (strength testing) will be used in commercial/industrial premises as a means of providing additional assurance.

The act of conversion naturally allows the industry to review current practices to assess whether there are areas that ought to be improved upon before a new gas is introduced. As an industry, one of the questions we are being asked is, “In properties due for conversion, what are we doing to assure the quality of pipework that we cannot access/see?”. Currently, a successful tightness test is taken as sufficient evidence to assure the quality of a gas installation, however, this test is only an instantaneous measure of tightness and does not allow for detection of potential failure modes in the pipework which may be activated over time.

Pipeline Inspection Gauges (PIGs) are used on the high-pressure gas network today to inspect sections of underground pipeline for changes in ovality/corrosion/potential leak sources etc. The question here is, is there a similar technique that can be introduced to smaller diameter, smaller pressure pipework, that allows a non-intrusive visual inspection of pipework in properties that we cannot currently access/see (i.e., because they are hidden in or behind the building fabric)?

Key Stakeholders
All UK GDNs (Cadent, NGN, SGN, WWU), British Gas

Target Market
Initially this will support the conversion of c. 2000 properties as part of the UK Hydrogen Village Trial. Depending on the UK Government policy decision in 2026, this could affect millions of customers who would be converted to hydrogen in the future.

Enablers and Constraints
One of the key constraints is that this inspection will be carried out in people’s homes and businesses and so must be suitable for implementation in those types of environments.

Currently, an NIA funded project is underway to look at the downstream pipework conversion strategy for hydrogen, research is being carried out into the potential use of novel inspection techniques, however, there doesn’t seem to be a ‘ready-made’ solution available.

The Hydrogen Village Trial is a key enabler to this work and there is definitely appetite for an innovative inspection technique to be introduced if it can be proved to be feasible.

Scalability and Target Implementation Date
If a solution is found and accepted, it will have to be incorporated into the overall conversion plan for the Hydrogen Village Trial. The conversion plan will dictate the required scale to enable 2000 properties to be converted in Spring/Summer 2025.

Document available to download here

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Problem Statement Title
EIP010 - Can we better predict fluid ingress?

Problem Statement Details
Fluid Ingress events are a common form of unplanned supply interruptions on the gas distribution network. This can range from interruption of supply to individual properties through to impacting 10,000s. The most common cause of fluid ingress on the gas distribution network is water ingress from fractured/burst water mains in the vicinity of the gas distribution network. This is followed by groundwater entering the gas distribution network via undetected points of ingress.

Water Ingress events can have significant difficult impacts for all customers, both residential and commercial, with remedial work often requiring extensive resource to rectify. Rectifying water ingress incidents can involve the requirement to vent significant volumes of gas to atmosphere to enable re-commissioning of the system. It can also require multiple large excavations across a local community to enable this re-commissioning. 

Other fluid ingress events that impact the gas distribution network include odorant pooling during times of low gas flow, and hydrate/oil deposits (a variety of causes).

Use of AI and system modelling is presumed to play a key part in supporting with developing solutions to this GB wide challenge. NGN is seeking solutions to improve the network’s capacity for predicting potential fluid ingress scenarios to enable prevention; this methodology will also support future distribution of low carbon gases across the network.

Key Stakeholders
Other GDNs, DNOs, Water Network Operators, Environment Agency, Customer Vulnerability Groups

Target Market
AI Solution providers, Technology Partners

Enablers and Constraints
Previous project: NIA_NGN_168 – Water Ingress Investigation.

Learnings can be taken from this previous work to understand how to apply technological advances since completion.

Scalability and Target Implementation Date
RIIO-GD3 and beyond, dependant on proposals. Solutions could be scalable across Network Operations, Investment Planning, Strategy & Customer Safeguarding Initiatives.

Document available to download here.

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Problem Statement Title
EIP011 - Can we detect PCBs in PMTs in situ?

Problem Statement Details
The changes introduced in the European Regulations (and in turn the 2019 UK PCB Regulations) require all UK DNOs to replace or PCB (polychlorinated biphenyl) test any pre-1987 oil-filled assets by 31st December 2025, due to PCB’s potential environmental impact as a Persistent Organic Pollutant (POP). These assets, which are mostly transformers, were accidentally contaminated with PCBs before the Stockholm Convention banned them in 1987. According to a statistical modem developed by the ENA PCB Working Group there are c. 88k transformers across all UK DNOs that need to be tested and/or replaced before the deadline. The majority of these assets are Pole Mounted Transformers (PMTs). While Ground Mounted Transformers (GMTs) can be relatively easily tested using existing equipment, PMTs are much more problematic due to the issues accessing and de-energising them; creating a tester that can test in situ with the asset energised would solve this problem.

Key Stakeholders
DNOs, Environmental contamination testing specialists, chemical labs, Environment Agency

Target Market
Around 88,000 transformers need to be tested/replaced before the deadline of 31st December 2025.

Enablers and Constraints
Previous NIA projects:

• WPD PCB Sniffer - This project was able to identify multiple solutions to test for PCB, but all of them required physical oil samples and hence cannot be used for live testing. This project concluded that there is no safe method of extracting oil from an overhead asset whilst it remains operational. It has also concluded that not all PCB congeners are present within the headspace of an asset under normal operating conditions and hence, headspace analysis isn’t an accurate testing method for the detection of PCBs. Also, there is insufficient spectroscopic data for all 209 PCB congeners to be able to use this method of detection and this would require a significant laboratory-based task. There is a deadline of 2025 to remove all potentially contaminated assets and this task would not be feasible within those timescales.
• SPEN On-Site Non-Intrusive Polychlorinated Biphenyls (PCB) Tester - The initial objective of this project was PCB determination through naturally existing gamma rays from Chlorine-36, with the recognised challenge of finding a detector that is sensitive enough. It was then changed to the use of a deuterium-tritium neutron generator, which has health and safety concerns as there will be additional radioactivity introduced. Participating DNOs decided to close-down the project due to health and safety risks as well as the timescale needed for understanding the incremental radioactivity and subsequently developing a suitable mobile device.

The need of the hour is a simple solution like a combination of Clor N oil test and swab test that can detect PCBs in transformer. The swab test solution exists in the US. The problem associated with sending the sample swabs to US is that they wouldn’t reach there within the required timeframe and hence the test will fail. A similar kind of testing centre needs to be established in UK. The transformer oil swab for the test can potentially be collected using live line rode from transformer ceramic bushings.

Scalability and Target Implementation Date
The solution is required as soon as possible and specifically prior to December 31st 2025 deadline.

There are some PCB testing kits available in the US as indicated above, however, no lab facilities exist in the UK to send the samples to.

Document available to download here

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Problem Statement Title
EIP012 - Can we better detect HV pre-faults?

Problem Statement Details
Research has taken place to understand the feasibility of detecting and locating HV defects before they turn into power cuts [Pre-Fix, DFA, Sine post].

There is increasing evidence that online techniques can direct staff to a broadly correct defect location before a protection operation. To operationally exploit this information, a fine-resolution location methodology is required before a repair can be planned. 

Because of the intermittent nature of these pre-fault pecks and the variance in the predicted location, use of test-van based techniques might not be the best way to deliver fine location at scale.

Because only small proportions of HV/LV substations benefit from being fitted with line connected current transformers (CT’s), approaches that promote on-line measurement of the suspect section will face barriers to scale. There is increasing evidence that the nature of the “pecks” that require detection act between phases (rather than phase to earth) and can be as small as +50 Amps (above base load) for less than one cycle before self-extinguishing.

Key Stakeholders
Operational teams within NGED. All other DNOs and potentially other utilities.

Target Market
Operational teams within NGED. All other DNOs and potentially other utilities.

Enablers and Constraints
It should also be remembered that any proposed techniques will need to be effective on the range of legacy HV cable types, which can include three phase and triplex style cables.

Scalability and Target Implementation Date
This may be applicable for the entire underground cable network of NGED and all other DNOs. There may be value to other utilities too. Target implementation date of April 2024.

Document available to download here.

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Problem Statement Title
EIP013 - Can we improve our cable-laying methods (11kV & LV)?

Problem Statement Details
Achieving Net Zero will require significant upgrades to the capacity of electrical distribution networks. Overlaying underground cables using existing trench-digging techniques is likely to prove time-consuming, expensive and disruptive to customers, especially in urban areas.We seek ways to upgrade our underground cable network quickly, cost-effectively, and with minimal disruption; this includes excavation, installation and backfilling.

Key Stakeholders
Operational teams within NGED, all other DNOs and potentially other utilities.

Target Market
Operational teams within NGED, all other DNOs and potentially other utilities.

Enablers and Constraints
The existing requirements for laying underground cables safely will need to be met by this project. The dimensions for cable trenches vary based on the rating, location and type of cable, and there are specific requirements for depth within agricultural areas. The cable trench bedding needs to be free from water and pieces of rock, and crushed limestone dust or crushed granite dust should be laid above and below the cable or duct.

The Alternative Cable Installation Methods (ACIM) – Phase 1 (Feasibility Study) | ENA Innovation Portal (energynetworks.org) project tried to find new ways to have longer distribution cable lays, meaning fewer joints – they settled on floating the cables in water. However, they found that there was no business case at 11 kV or lower, and it was marginal at 33 kV. They also had no sites to test this, so ended up halting the project prematurely.

The objective of the Mini-Mole | ENA Innovation Portal (energynetworks.org) project was to identify a safer, less disruptive and more resource efficient way of repairing and replacing LV and Service cables, so as to provide an improved service to our customers. The gas networks often use ‘moles’ to dig between two pits and avoid the need for open trenches, however these pits typically need to be very large to enable an operator to situate the mole correctly. At the time of writing, we were unable to determine the outcomes of the Mini-Mole project, but will be looking to get in touch with SPEN to confirm the project outcomes and learning.

Scalability and Target Implementation Date
This may be applicable for the entire underground cable network of NGED and all other DNOs. There may be value to other utilities too. Target implementation date of April 2024.

Document available to download here.

View presentation slides here

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Problem Statement Title
EIP015 - Can we reduce the cost of excavating pipelines?

Problem Statement Details
We need to excavate our buried assets for a number of reasons including repair, inspection and data gathering. As our pipelines are of a significant size and mostly located in rural areas, access can be difficult, and the resultant excavation needs to be large to allow safe personnel entry. For these reasons excavation can become quite expensive and require a long time to complete.

Therefore, are there better ways to either reduce the size of excavation or remove the human element from the task?

Key Stakeholders
Hydrogen, Operations, Construction

Target Market
Water, Telecoms

Enablers and Constraints
The Robotic Roadworks and Excavation System (RRES)

https://smarter.energynetworks.org/projects/sgngn04/

Scalability and Target Implementation Date
RIIO-2, RIIO-3 and onwards.

Document available to download here.

View presentation slides here

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Problem Statement Title
EIP016 - How do we eliminate emissions on the NTS?

Problem Statement Details
Emissions reduction techniques have been developed and are in deployment, however, we still emit CO2 and leak natural gas. We need novel solutions to prevent all emissions from the gas network.

Alongside this we also need novel, low cost, easy-to-deploy solutions to find leaks on the network, and then work to prevent them (or if unavoidable, capture them to be put back into the network). This should cover emissions from our pipelines and above ground installations.

Key Stakeholders
Operations, Commercial

Target Market
Gas Transmission

Enablers and Constraints
Enablers; the prior projects outlined below:

Monitoring of real-time Fugitive Emissions (MORFE) https://smarter.energynetworks.org/projects/nia_nggt0137/

CH4RGE – Methane Reduction from Gas Equipment

https://smarter.energynetworks.org/projects/nia_nggt0164/

CH4RGE – Methane Reduction from Gas Equipment – Phase 2

https://smarter.energynetworks.org/projects/nia_nggt0174/

Scalability and Target Implementation Date
RIIO-3 onwards

Document available to download here.

View presentation slides here

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Problem Statement Title
EIP017 - Is there an alternative to pipe cladding?

Problem Statement Details
Cladding around pipelines is needed for a variety of reasons including for thermal reasons and to prevent sound pollution. However, where this is applied around our above-ground pipework, it can lead to issues with corrosion and a lack of ability to inspect the pipeline.

As an industry now and in the future, we need either a way to clad our pipes that prevents corrosion and allows inspection, or alternative methods to prevent the sound pollution and thermal constraints without cladding.

Key Stakeholders
Asset, Operations

Target Market
Gas, Nuclear, Construction, Automotive, Aerospace, Maritime

Enablers and Constraints
NIA_NGGT0127: Valve Pits Insulation - https://smarter.energynetworks.org/projects/nia_nggt0127/

Scalability and Target Implementation Date
RIIO-3 onwards

Document available to download here.

View presentation slides here

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Problem Statement Title
EIP018 - Can we automate vibration monitoring on AGIs?

Problem Statement Details
Vibration monitoring on above-ground installations (AGIs) is limited today. An alternative to manual vibration monitoring and assessment is required – one which can be automated and include alarm settings for when vibration patterns are altered. Vibration monitoring is a challenge on today’s assets and will continue to pose a challenge in a hydrogen future, especially if flow rates are increased. Any solution will need to be retrofitted to existing assets, fitted within new assets, be ATEX-certified to work in hazardous areas, and be able to communicate to central systems for monitoring.

Key Stakeholders
Hydrogen, Operations, Construction, HR

Target Market
Gas, nuclear, construction, automotive, aerospace, maritime… (i.e., any industry managing vibration)

Enablers and Constraints
NIA_NGGT0038: Novel vibration measurement technologies https://smarter.energynetworks.org/projects/nia_nggt0038/

Scalability and Target Implementation Date
RIIO-2, RIIO-3 and onwards. 

Document available to download here.

View presentation slides here

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Problem Statement Title
EIP022 - Can we marry network monitoring and management?

Problem Statement Details
There are several commercially available LV and HV monitoring equipment/solutions which provide impedance-to-fault values for either pre-fault or post-fault events on distribution networks. Converting these impedance-to-fault values to physical locations on networks (e.g., X metres along feeder Y) is typically a manual process which involves support teams carrying out some network modelling or reviewing GIS records to identify cable and overhead line types and characteristics.

In addition to identifying the above, there is a manual process in informing Network Control Engineers and field crews of these pre-fault/post-fault locations - see Figure 1 and Figure 2 on PDF.

Key Stakeholders
Network Control – The solution will enable automated notification to Network Control Engineers and allow them to carry out timely switching on the network to isolate faulting/faulted network sections.

Network Operations – The solution will enable field crews to find the actual location of faults more quickly (for post-fault events) and carry out pre-emptive repairs for pre-fault events.

Asset Management – The solution will remove the need for dedicated roles to carry out the annual tasks associated with identifying pre-fault/post-fault locations and notifying stakeholders. It would also remove the need (and associated costs) for third parties to provide these services.

Target Market
This solution will provide most value for managing LV and HV faults. By either acting pre-fault or locating and responding to post-fault events quicker, customers will see a direct benefit through a reduction in CIs and CMLs.

Enablers and Constraints

• The solution must be technology agnostic, i.e., take impedance to fault values as input from sensors and monitoring solutions from many suppliers in order to provide a location.
• Examples of innovation projects that provide fault locations include but are not limited to: HV Feeder monitoring to pre-empt faults, MILES and Arc Aid.
• The output of the solution must integrate with our current Network Management System, GE PowerOn/ADMS.
• Comprehensive records of LV and HV cables and overhead line conductors are required to calculate pre/post fault locations.
• A key enabler is fully digitised network records (particularly for LV and HV cables and overhead lines).

Scalability and Target Implementation Date
The target date for successful implementation is mid-2024. The solution could be scalable to other DNOs if they have the pre-requisites:

• Commercially available monitoring solutions that provide impedance-to fault values as outputs.
• Fully digitised network records (particularly for LV and HV cables and overhead lines).
• Comprehensive records of LV and HV cables and overhead line conductors.
• Network Management Systems with enhancement capabilities. 

Document available to download here.

View video presentation here

Problem Statement Title
EIP048 - Can we prevent outages from new connections?

Problem Statement Details
SSEN Transmission has ambitious targets set over the coming years with renewable energy in the North of Scotland set to grow exponentially. By 2050 we anticipate that approximately 50 GW of renewable energy will be connected to the network - from a variety of on-shore and off-shore sources. This is a significant shift from the 8 GW currently connected, so over the coming years, we will undoubtedly face new challenges that will need to be overcome to deliver this network of the future.

As we connect more energy to our network, the process can cause significant disruption to the network and the surrounding environment. One key disruption is the need to apply network outages to enable the required reinforcements. Outages are inherently complex, and not only do they impact our customers, but the planning process takes significant time and alignment; it can add significant time to the overall process.

We need to identify new methods to minimise this disruption, and so we are interested to investigate opportunities that can:

1. Minimise overall outage times, and/or;
2. Prevent the need for an outage.

The most desirable outcome would be to prevent the need for an outage, but we feel it is important that solutions can also be identified to minimise the disruption. In considering the prevention of any outage, we are keen to understand workarounds. This would be a solution that allows for part or all of the reinforcement works to continue without the need for circuit isolation.

Key Stakeholders
Network operators, renewable generators, local communities, energy consumers.

Target Market
Albeit this challenge is categorised against Optimised Assets and Practices, the intended solution(s) have the potential to have applications across the Whole Energy system (both gas and electricity).

Enablers and Constraints
There have been various innovation projects in the past that have considered modular or temporary mobile solutions. Initial consideration should be made around the successes and failures of the approaches used in these examples.

Scalability and Target Implementation Date
As significant works are already underway across much of the SSEN Transmission network, new solutions and methods are needed right away to prevent further delays on future projects. As a result, there is significant interest in identifying new innovative solutions that have the potential to be deployed in the RIIO-T2 period. This essentially drives the requirement for higher TRL solutions; however, we will not limit ourselves to opportunities that may require further research with a protracted implementation time.

Document available to download here.

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Problem Statement Title
EIP049 - Can we reduce our construction times?

Problem Statement Details
SSEN Transmission has ambitious targets set over the coming years with renewable energy in the North of Scotland set to grow exponentially. By 2050 we anticipate that approximately 50 GW of renewable energy will be connected to the network - from a variety of on-shore and off-shore sources. This is a significant shift from the 8 GW currently connected, so over the coming years we will undoubtedly face new challenges that will need to be overcome to deliver this network of the future.

One of the key challenges is the significant complexity around constructing a network of this scale. Time is one of our biggest factors, and we need to focus our attention on reducing overall construction times across all projects to enable the timely delivery of our plans. This scale of growth has never been experienced before in our network area, so this will inevitably drive the need for new innovative solutions to overcome the various obstacles along the way. We need to discover new methods that can alleviate the pressures of building these infrastructure types our Substations and Overhead Lines (OHL).

Across these infrastructure types, we would like to focus on two main challenge themes:

1. New construction methods and practices – this should consider the full programme life cycle, from design to energisation that identifies new methods or approaches to reduce overall programme time.
2. Supply Chain Efficiencies – identify new methods and practices that target the key supply chain performance metrics (Time, Cost, Quality) to enable greater efficiencies whilst minimising waste across each metric.

Key Stakeholders
Network operators, renewable generators, local communities, energy consumers.

Target Market
Albeit this challenge is categorised against Optimised Assets and Practices, the intended solution(s) have the potential to have applications across the Whole Energy system (both gas and electricity).

Enablers and Constraints
The OHL Foundation Uplift NIA project is an example of work underway to identify improvements in OHL foundation designs. The scope of this project is expected to identify design methods that can deliver greater efficiencies and reduce overall time and materials in this construction method.

OHL Foundation Uplift | ENA Innovation Portal (energynetworks.org)

Scalability and Target Implementation Date
As significant works are already underway across much of the SSEN Transmission network, new solutions and methods are needed right away to prevent further delays on future projects. As a result, there is significant interest in identifying new innovative solutions that have the potential to be deployed in the RIIO-T2 period. This essentially drives the requirement for higher TRL solutions; however, we will not limit ourselves to opportunities that may require further research with a protracted implementation time.

Document available to download here.

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Problem Statement Title
EIP029 - How should we communicate with vulnerable customers?

Problem Statement Details
GDNs need to further understand the risks associated with a lack of engagement, lack of understanding, ineffective communication and unwillingness to pay within vulnerable customer groups.

Additionally, the GDNs need to further understand how these can be positively addressed to provide the very best outcomes for our customers.

Key Stakeholders
Other GDNs, DNOs, Customer Vulnerability Groups, Social Housing (Landlords), Local Authority Housing Associations etc, Local MP/Stakeholder Groups

Target Market
Marketing & Engagement Strategists & Key Stakeholder Input Groups

Enablers and Constraints
No previous projects that primarily focus on developing a greater understanding of future unplanned interruption scenarios & the support required for customers in vulnerable situations.

Scalability and Target Implementation Date
RIIO-GD3 and beyond, dependant on proposals.

Solutions could be scalable across Network Operations, Investment Planning, Strategy & Customer Safeguarding Initiatives.

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Problem Statement Title
EIP030 Can we minimise unplanned supply interruptions?

Problem Statement Details
During Year One of RIIO-GD2, the average unplanned gas supply interruption duration for NGN was 5 hours across a total 10,778 interruptions. Unplanned Gas Supply Interruptions are commonly caused by:

• Network supply issues (poor pressure, water ingress)
• Third party interference damage
• Unforeseen Network Interruptions during REPEX Activities.

There is an appreciation also that during any future gas network conversion activities, there will be an increase in excavation activities within the vicinity of buried utilities, increasing the risk of damage and subsequent interruption. Gas Supply Interruptions have significant impacts across all customer bases; however, it is known that supply interruptions have a greater detrimental impact for Customers in Vulnerable Situations. The Energy System Transition will result in varying impacts following unplanned interruptions, dependent on the type of energy system to which they are connected.

NGN are seeking a greater understanding of what future supply energy system supply interruptions may involve and how we can work to minimise and eliminate future supply interruption.

Key Stakeholders
Other GDNs, DNOs, Customer Vulnerability Groups

Target Market
Technology Partners

Enablers and Constraints
No previous projects that primarily focus on developing a greater understanding of future unplanned interruption scenarios & the support required for customers in vulnerable situations.

Scalability and Target Implementation Date
RIIO-GD3 and beyond, dependant on proposals. Solutions could be scalable across Network Operations, Investment Planning, Strategy & Customer Safeguarding Initiatives.

Download full document here

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Problem Statement Title 
EIP031 How can we increase uptake of the PSR?

Problem Statement Details
We estimate that there are around 3.5 million people across UK Power Networks’ regions that are in vulnerable circumstances and are eligible for additional support in the event of power outages through the Priority Services Register (PSR). UK Power Networks is currently only aware of and subsequently able to offer support to 62% of these customers.

As a socially responsible corporate citizen, we have committed to substantially increasing the uptake of these priority services to 86%, equating to over 800,000 new registrations to the PSR, to ensure that all customers that are vulnerable and eligible have the support from the PSR and UK Power Networks that they need. This is particularly important now in the social and economic context of the Cost-of-Living crisis where an increasing number of people are in need.

We need to identify and register over 800,000 new customers onto the PSR in ED2

Why is this a challenge?
Identifying the customers that are eligible becomes increasingly difficult as each incremental improvement comes at an increasingly higher cost to find those that are increasingly hard to reach.
Why is this a challenge?
Eligible customers may not know they are eligible or understand the benefits of the PSR and therefore don’t proactively register. Subsequently, UK Power Networks must proactively find those that are eligible.
Why is this a challenge?
UK Power Networks has utilised a range of data sources and tools to better identify these customers in RIIO-ED1, however, to meet this scale of ambition, further solutions are needed.
Why is this a challenge?
We need to find new ways to identify customers, educate them about the benefits of the PSR and encourage them to register for the PSR in order to register more people in the first two years of RIIO-ED2 than UK Power Networks managed in all of RIIO-ED1.

Countermeasure: We need to go beyond traditional methods and find innovative ways to identify and reach these hard-to-reach eligible vulnerable customers.

We’ve also established a business PSR during the last year of RIIO-ED1. We have the ambition of registering over 600,000 SME businesses in vulnerable circumstances.

SME business in vulnerable circumstances is defined as follows:

• Operation is susceptible to a single power outage caused by factors outside its control, which regardless of duration:
– Has the potential to significantly impact the lives and wellbeing of its employees or customers.
– Impacts the business operations to such a degree that it results in material financial loss to the business.
• Main point of contact has an impairment or communication need that, when identified, requires adjustments to ensure all communication from us is accessible.
Identifying and registering these customers follow similar challenges to those faced in the domestic PSR.

Key Stakeholders
Eligible vulnerable customers that are being denied the benefits and support of being on the PSR. See eligibility here: About the Priority Services Register | UK power networks.
SME businesses in vulnerable circumstances.

Target Market
Over 800,000 eligible vulnerable customers within the UK Power Networks licence area that are not currently on our PSR. Similarly, 600,000 SME businesses in vulnerable circumstances.

Enablers and Constraints
Tools overlaying socio-economic data sets – built geospatial tools (Socially Green) that layer national vulnerability datasets. This allows us to map and understand key areas of vulnerability and thus focus our efforts in those areas. Successful in the past but decreasing marginal improvements as a decreasing number of our customers show up on these datasets (hard-to-reach).
Data sharing – Currently sharing PSR data with water companies. This has been relatively successful but limited ability to scale in the future as the thinking needs to evolve to consider wider data which currently aren’t accessible due to data protection constraints.
Resource sharing between DNOs – in progress currently. Platform that all DNOs could send all customers centrally to register for the PSR. Unknown success rate but mostly DNOs will focus campaigns in their own areas
Approaches raising awareness – Traditional approaches and channels have been used to date. Opportunity to consider new innovative approaches to raising awareness and encourage registration.

Scalability and Target Implementation Date
The aim is to identify and register these individuals as soon as possible to ensure they get access to the support as soon as possible. Solutions will also be scalable to other energy networks within Great Britain.

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Problem Statement Title

EIP032 How can we reach PSR customers without mobiles?

Problem Statement Details
BT Open Reach is in the process of transferring telephone lines from the traditional public switched telephone network (PTSN) links to digital links – either fibre to the cabinet (SoGEA) or to the premises (FTTP). This will mean that the landline telephone in a customer’s property will no longer be powered from the telephone exchange as is currently done with the PTSN links.

During a power cut customers will no longer be able to make calls if they don’t own or have access to a mobile phone or live in areas with poor mobile coverage; nor will it be possible to contact them via a landline during a power outage – a particular concern for highly vulnerable Priority Service Register (PSR) customers. Similarly, the red button care alarm systems will not function, nor will existing emergency phone systems, such as those provided within substations, at train crossings, in lifts…

What is required is an alternative way to know that a PSR is off supply and/or a means to communicate with them to provide them updates and check whether they need help.

Key Stakeholders
DNO customer services teams – interested in communicating with PSR customers to provide them the right support during a power cut.

PSR customers (and carers/designated contacts of PSR customers) – interested in receiving communication from the DNO during a power cut to receive appropriate support and advice.
Communication Providers – interested in areas where PSR customers exist and identifying how the proposed solution will interface with their services.

BT Open Reach – interested in areas where PSR customers exist and have good reason to be unable to switch from copper to full-fibre products and require extended copper-based service support.
Energy suppliers – interested in identifying how the proposed solution would interface with their products and services.

Target Market
An estimated 157,000 PSR customers in UK Power Networks licence area who do not have a mobile phone registered on their account; 11,000 of those customers would be registered with a medical dependent code. Typically, those who do not have a mobile phone are thought to be elderly and are more likely to need support in the event of a power outage.

Enablers and Constraints
BT are providing vulnerable customers with a battery backup unit which lasts for a minimum of one hour.
Virgin is providing an Emergency Backup Line for customers who have accessibility needs or don’t have a mobile phone. It is a small box that connects the fibre phone line from the Hub to the home phone handset and connects to the mobile network to call emergency services only. It is intended to provide eight hours of standby and one hour of talk time if disconnected from the mains supply and will only be offered to customers in areas with mobile coverage. However, the solution will not be provided to customers where there’s no mobile coverage, and Virgin will not offer fibre phone lines either. If the power outage also extends to the mobile mast, there will not be any mobile phone coverage either (mobile masts tend to have up fifteen minutes to one hour of emergency backup). A portion of the target market is likely to not have broadband connections, and the emergency backup line is not currently advertised to new customers, nor is it mentioned as part of installation services, limiting knowledge access to those who visit their website.

The elderly are likely to store a rarely used mobile phone in a drawer, where the battery is likely to be discharged.

Scalability and Target Implementation Date
BT are planning to complete the fibre optic transition by December 2025 (c. twelve million landlines) and as such the solution should be rolled out at the latest by end of 2024.
The resulting technology could be rolled out to all PSR customers across Great Britain.

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Problem Statement Title
EIP051 Can technology engage hard-to-reach customers?

Problem Statement Details
How can the GDNs use technology to ensure that messages and information is accessible and engaging for all? This is particularly seen as a challenge for customers with poor English, those with mobility and cognitive challenges, and to reach school children who are the customers and bill payers of the future.

Key Stakeholders
Gas and Electricity Networks, domestic customers/particularly those in vulnerable situations, housing associations and private landlords, local authorities/resilience forums, local health organisations.

Target Market
Messages could be about energy saving advice, the Priority Service Register, gas safety and carbon monoxide awareness, and the future of energy.

This is particularly seen as a challenge for customers with poor English, those with mobility and cognitive challenges, and to reach school children who are the customers and bill payers of the future.

Enablers and Constraints
We have the ability to translate materials in written and electronic form but with multiple dialects even within a community that does not always work.

Customers may have access to devices and be able to access materials from their home – alternatively we may want to utilise materials in a community setting.

How can we engage the younger customers? Previous work on carbon monoxide shows that gaming scenarios work well for some audiences. Can we apply this to other topics?

Scalability and Target Implementation Date
Initially we want to trial solutions with local community groups and individuals – there is a need to do this now on topics such as energy advice, the Priority Service Register and carbon monoxide. We would then want to make tools and resources available to multiple community groups to cascade through their local networks.

Customers are also becoming more aware of the future energy challenges for the UK, and that the way they heat their homes may change. We need to build tools that can be accessed en masse, to start the education of customers ahead of real change from the 2030s – ensuring that no-one is left behind.

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Problem Statement Title
EIP052 How can we protect customers during supply interruptions?

Problem Statement Details
How can the GDNs keep customers warm and safe during gas supply interruptions?  Existing measures often require plugging in a device - which customers are more reluctant to do given energy costs and wider cost of living crisis.  Mass deployment of temporary electrical appliances (2 kWh fan heaters, 2 kWh oil radiators, hot plates, electric blankets...) can also cause issues to the electricity grid at peak times.

Future gas network conversions from natural gas to hydrogen will see a large increase in the number of customers facing interruptions for longer periods than with our current planned work, so low-cost solutions that take the cost worry from the customer are required.

Key Stakeholders
Gas and Electricity Networks, British Gas, domestic customers – particular those in vulnerable situations, housing associations and private landlords, local authorities – resilience forums, local health organisations.

Target Market
Customers who are impacted through a lack of heating or the ability to cook hot meals due to the gas supply interruption - these are generally older people, those with health conditions and families with young children, but everyone can be vulnerable if the interruption is over a number of days and the temperature is low.

Enablers and Constraints
We are interested in existing products or adaptations of existing technology rather than proto-typing new devices due to the challenges of productionising. Devices need to be portable and deployable en masse by engineers and customer support staff in cars and small vans.

There is not yet visibility of the effects on the electricity networks of customer behaviour off-gas.

Some engagement with Ofgem may be required to determine how networks can satisfy GSOP without necessarily giving power options.

Scalability and Target Implementation Date
Networks have obligations to offer and provide alternative heating and cooking to customers on the Priority Service Register (around 22% of homes).  With 10,000s homes interrupted each year due to planned replacement works and emergencies - including the occasional incident with a large number of homes impacted - there is an immediate demand for alternatives to traditional support.

A hydrogen conversion programme in the future would see 1,000s of homes interrupted daily with a roll out likely to start in the 2030s.

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Problem Statement Title
EIP053 How can we maximise use of demographic data?

Problem Statement Details
Networks have embarked on digitisation strategies to share asset data to aid the UK energy transition. How can we additionally use demographic data to support the creation of programmes of works? Can this data assist in the planning of projects which improve the experience of the customer and communities?
The data is the enabler, the innovation here is how we use the data to drive decision-making.

Key Stakeholders
Gas and Electricity Networks, domestic customers/particular those in vulnerable situations, small and medium businesses, sousing associations and private landlords, local authorities/resilience forums, local health organisations.

Target Market
GDNs and DNOs should be considering the demographics of an area as part of the planning of projects, such that they can ensure initial communications are tailored to the area and support measures planned are available. During incidents, identification of the demographics of the area including businesses, schools and healthcare facilities would help the response and safeguarding of the population. As we move towards a hydrogen roll out and some parts of the gas network potentially being disconnected, it is important we understand the demographics of who will be adopters, who will need support and those at risk of being left behind.
Networks have additional funding from Ofgem, so data-driven targeting of projects to the most in-need areas is important.

Enablers and Constraints
Enabler: GIS systems can be loaded with demographic data, and with updated dataset sets from the 2021 census becoming available, the timing is right to identify and utilise the applicable datasets.
Data should be freely available as a principal and overlaid with asset data to allow spatial analysis.

Scalability and Target Implementation Date
Whilst networks all have some data in different formats and with different means of access, a consistent set of data, use-cases and outputs would aid networks, and demonstrate to customers/consumer groups a joined-up approach to current and future challenges.

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Problem Statement Title
EIP057 How can we convert without interrupting supply?

Problem Statement Details
During the process of conversion, we will interrupt the customer on a number of occasions. How do we convert without interrupting, working to maintain continuity off supply for customers in vulnerable situations? This will also reduce the need of alternative heating and cooking appliances thereby reduced costs for the Gas Network and the customer.

Key Stakeholders
All our customers especially those in vulnerable situations, gas network operators.

Target Market
Gas Network

Enablers and Constraints
Enablers - We know who our customers in vulnerable situations are; we have a conversion plan.
Constraints - Interruptions currently take at least four hours and this may be on two occasions. Solutions are needed by 2026 when we will start to see the first hydrogen village and blend networks.

Scalability and Target Implementation Date
If an appropriate solution is found this can be scaled to use across all gas networks and not just for customers in vulnerable situations, not just hydrogen roll out but across many of our existing workstreams. 2026 target implementation date.

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Problem Statement Title
EIP061 How can we tackle inequity in the transition?

Problem Statement Details
Discontinuities like the energy system transition favour those with the capital, knowledge or connections to survive and profit from the change - this will disadvantage the majority of the population. The majority of the population do not have access to the resources to participate beneficially in the energy system transition (EST).

Identification of new technologies and new systems of technologies are required to address physical inequity. Identification of new funding methods and commercial offerings are required to address physical inequity.

Key Stakeholders
Energy users.

Target Market
50%+ of 30,000,000 users.

Enablers and Constraints
Must not hinder the energy system transition, must encourage broad societal support for and take up of the EST, must consider technical, economic and social aspects of adoption across different demographics.

Scalability and Target Implementation Date
Required ASAP, however roll-out timescales will depend on solution type and the roll-out logistics that imposes. Similarly for scalability.

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Problem Statement Title
EIP007 - How does extreme heat impact network assets?

Problem Statement Details

The strain that extreme heat poses on critical infrastructure is unknown, let alone the impact of rapid temperature stepped change (e.g., Denver experienced a 65^oC drop from 50^oC to -15^oC in just 16 hours).

We know heat and cold waves affect the normal operation of electrical components. With climate change, these phenomena will be on the rise and hence a proper optimisation analysis is imperative to control the associated risks, especially for the aged equipment.

Some coordinated approach to optimise assets output and equipment operations in substations is necessary to support clean energy delivery even under extreme heat situations. Optimising in extreme heat or rapid temperature fluctuations in a power system environment is key.

Currently, there is no method to clearly indicate how service delivery is affected by rapid heat changes and high temperature occurrences. Research to-date includes literature on efforts underway in improving risk modelling and strategies for other extreme weather events besides heat.

Heat waves may lead to power system malfunctions that can disrupt service delivery or in worst cases relatively short outages.

Key Stakeholders
Asset Management Teams and System/Network Operators across all network operators (e.g., NG, TNOs, DNOs, ESOs).

Target Market
Assuring cheaper and adequate power supplies under extreme weather conditions to millions of customers.

Enablers and Constraints
Enablers: Asset management strategy and policy; resilience strategy.

Scalability and Target Implementation Date
Once the solution has been presented and approved, a pilot phase to implement the solution can be run at NGET’s Deeside Centre of Innovation during 2023/24.

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Problem Statement Title
EIP008 - Can we be more resilient to multi-hazard weather events?

Problem Statement Details
Weather related hazards are often assessed in isolation with little understanding on the complexities of how different hazards interact with each other and over what period an individual risk may leave us vulnerable to another hazard.

This was seen in the recent June 2022 Yellowstone flooding in the US, where a greater-than-average snowpack was experienced followed by a much warmer-than-normal spring. This caused a rapid melting, followed by wetter-than-normal early summer rainfall, which resulted in catastrophic flooding. Each of these incidents considered in isolation would not have caused concern, however the cumulative and amplification was catastrophic.

The problem of multi-hazard weather events happening within the same location and time must be critically analysed to manage probability of cascade failures which are a growing concern as one the main mechanisms causing widespread blackouts of power networks.

Currently, no matrix exists to fully incorporate resilience against such multi-hazards which are forecasted to increase with climate change. Current research has been looking at resilience against specific individual weather events.

Key Stakeholders
Asset Management Teams and System/Network Operators across all network operators (e.g., NG, TNOs, DNOs, ESOs)

Target Market
Ensuring the security of supply and keeping the lights on for millions of customers everyday even under extreme weather conditions.

Enablers and Constraints
In some cases, the individual risk is somewhat understood. Current design standards typically consider risk in isolation.

Scalability and Target Implementation Date
The solution can latch on the use of existing data and tools to produce a model which can be easily integrated into NGET’s risk management system with RIIO-T2

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Problem Statement Title
EIP019 - Can we minimise cable-fault supply interruptions?

Problem Statement Details
The SPM Network design historically involved a unit protected system at 11 kV (X-Type). However, due to the ongoing complexities and costs associated with the X-Type network, many circuits have been converted into the traditional Y-type arrangement under modernisation. The Converted Network is often still run interconnected between Primary Substations, and any LV network interconnection would remain. This can be problematic – during the event of an HV fault, traditional fault finding and restoration techniques cannot be utilised due to the risk back feeding an HV fault via the LV network. In this situation, alternative techniques for fault restoration are required, which can be prolonged due to the complexity of the interconnection.

We are looking for methods to solve this complexity by aiding fault location/restoration, and ways to segregate the meshed LV network during a HV fault.

Key Stakeholders
DNO’s, Fault Engineers, Customers

Target Market
Interconnected Network Operators, DNOs

Enablers and Constraints

Enablers:
New Secondary RTU with enhanced IO and Modern Telecoms infrastructure being rolled out.

Constraints:
Limited LV Smart Devices to isolate interconnection, fault-finding techniques that don’t require a VICTOR.

Scalability and Target Implementation Date
Following successful trial of any solutions a wider roll out will be considered.

Any learning or developments will be shared with other DNOs to allow for adoption.

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Problem Statement Title
EIP021 - Can nature-based solutions mitigate flood risks?

Problem Statement Details
A desktop assessment of primary substation sites across SEPD and SHEPD licence areas was carried out as part of RIIO-ED2 business planning, identifying 65 of them as at risk of flooding.  The assessment scored the sites based on flood risk and proposed flood defence measures, resulting in a total of 51 sites being identified in SEPD and 14 in SHEPD. 

Currently, only traditional hard-engineering solutions have been proposed, and these can be costly, carbon intensive and may not deliver wider social and environmental benefits.

SSEN are looking to identify nature-based solutions which would deliver the desired flood mitigation in a more sustainable way – with additional biodiversity benefits, while also providing flood protection for the surrounding landscape (not just our substations). As the sites are varied in type, location and environment, a number of different options may need to be considered.

It is believed that a nature-based solution, if chosen over a typical permanent hard-engineering solution, would bring additional benefits around:

• delivery of flooding resilience at lower cost
• lower embodied carbon
• wider ecosystem benefits – carbon sequestration, water quality, air regulation…
• biodiversity enhancements
• community/societal benefits – reduced flooding of property, leisure opportunities in nature…
• DNO-wide benefits in new approach, establishment of new best practice.

DNOs have an obligation to address the risk management of floods at grid and primary substations due to coastal, river and surface water flooding. The aim of the ETR138 is to provide guidance on how to improve the resilience of substations to flooding to a state that is acceptable to customers, Ofgem and Government.

Key Stakeholders
SSEN: Portfolio Management, Asset Policy and Sustainability teams.

Consumers: those located in catchments where nature-based solutions are delivered would benefit from improved local environments. If the approach demonstrates a cost saving in flood mitigation delivery, this saving is passed onto the customer in the form of reduced network charges.

Regulators, the Scottish Environmental Protection Agency (SEPA), the Environment Agency (EA).

Target Market
SSEN: Up to 65 primary substation sites across SEPD and SHEPD; with the option to include other assets once further modelling is carried out. Additional modelling and analysis of SEPD and SHEPD would be beneficial to identify other assets at risk of flooding.

Other: other DNOs, water companies, housing developers, rail and road industries;

Enablers and Constraints
Enablers:

To date, there has been no other work on nature-based solutions for flood mitigation carried out in SSEN.  Initial research shows that potential solutions may include:

• re-wetting upland peat bogs as natural storage reservoirs
• beavers as ecosystem engineers
• restoring river channels and meanders
• plant trees and hedges to increase water absorption, catch rainfall and slow down surface water run-off1
• improve soil cover with plants to reduce water pollution and run- off1
• divert high water flows and create areas to store water1 (i.e., Swales and SUDS)
• create leaky barriers to slow water flow in streams and ditches1
• restore salt marshes, mudflats and peat bogs1

(1Taken from https://www.gov.uk/guidance/use-nature-based-solutions-to-reduce-flooding-in-your-area)

There are also other avenues which could be utilised as source of experience in this area:

• Partnership working to leverage other funding sources/pool resources for innovative solutions e.g., within the water industry
• Partnership working for expertise e.g., The Rivers Trust, Catchment-Based Approach (CaBA).

Constraints:

• Catchment scale work is likely to require permits/consents from environmental regulators e.g., re-profiling or adding woody debris and leaky dams to water courses would require permissions from SEPA or the EA.
• Ideally, the trial site would be within our SEPD area as a lot more data is available, and flooding is a much bigger issue there than in the SHEPD area.

Scalability and Target Implementation Date
No ‘hard’ implementation date, however, would ideally be implemented as early into ED2 as possible to maximise the benefits. In the absence of alternative solutions, traditional engineering methods will be utilised in the meantime.

Document available to download here.

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Problem Statement Title
EIP023 - How can we better serve our Worst Served Customers?

Problem Statement Details
Recognising limitations in its Interruptions Incentive Scheme (IIS), Ofgem introduced the WSC mechanism in 2010. The mechanism allows DNOs to invest in the network for customers experiencing the very worst quality of supply (QoS) that otherwise would not attract network investments, including IIS.

During RIIO-ED1, the mechanism allows DNOs to invest where customers experience twelve or more high-voltage faults over a three-year period with a minimum of three faults in each of the three years. For RIIO-ED2, Ofgem has worked with DNOs to review the WSC mechanism. As well as changing the qualifying threshold – reducing the minimum number of high-voltage faults in each year to two, while keeping the overall number of faults at twelve – Ofgem has enhanced the mechanism, making it more flexible, removing the efficacy constraints that limited available scope and solutions, thereby allowing DNOs to bring forward more significant mitigation.

Despite these changes, the mechanism remains purposely specific and narrow in its scope. The result of the qualifying criteria changing means that more customers will be classified as worst-served and spread more thinly across the network topology. This results in smaller pockets of customers experiencing poor levels of service.

Traditional network reinforcement, particularly involving undergrounding of overhead lines, overlay of old cable, or ringing in HV spurs/tees can take two or more years to deliver – often held up by legal consents. Furthermore, these solutions may be seen as not cost effective when involving only 1-50 customers.

An aging population has resulted in an annual increase in customers that can be deemed as vulnerable, many of which are on the Priority Services Register (PSR), related to e.g., age and medical needs. This number is predicted to increase through the course of RIIO-ED2, with customers becoming more reliant on a resilient electricity network. Many of these PSR customers are located in remote rural areas where restoration times post-fault may take longer. Additionally, there may also be reliance on electricity for local water pumping stations for example, either fresh or sewerage, and loss of these would further impact vulnerable customers.  

Key Stakeholders
Worst Served Customers – improving the quality of supply to these customers will benefit this group.

Network Operations – A more reliable/resilient network would mean that a network fault is less likely to occur. Enhancement of the network should also mean quicker response is possible if, for example, better network automation is in place.

Network Control – Remote control of the network shall be enhanced.

Asset Management – The solution would allow quicker enhancement of the electricity network by Network Planning Teams, and potentially less reliance on a legal wayleave/easement process.

Target Market
UK Power Networks plans to invest up to £28m which will deliver at least 25% improvement in reliability for eligible WSCs. We expect that the equivalent of 10,000 customers per annum will see an improvement in the reliability of their power supplies from this investment. Where costs of traditional solutions prohibit their implementation, we wish to find innovative solution to improve service received by WSCs.

Vulnerable customers would see an improvement to their service in a shorter timescale than is allowed by traditional types of reinforcement. This solution would be directly beneficial to UK DNOs with Rural or mixed Urban/Rural type networks, particularly those with Worst Served Customers as defined by Ofgem.

Enablers and Constraints

• Customer data enables us to pinpoint where our PSR customers are located which would help with delivery of targeted improvements/solutions.
• Differing Network Standards across DNOs could require alternative solutions.

Better Spur Protection was a UK Power Networks’ innovation project that aimed to see whether Fuse Savers could be installed on “clean” feeders that do not have reclosers and auto-sectionalising links (ASLs) and prove if they could operate in a superior fashion to ASLs and provide greater information regarding normal and fault conditions on the spur. Customers would benefit from the Fuse Saver as the feeder would retain the current level of protection but without the short interruptions that occur from the reclosers operating to activate the ASLs. The project proved the device worked as expected, could be safely installed by HV live line teams, and could work in the same manner as an ASL. However, this project only addressed short interruptions and ensuring these customers remain on-supply during a power cut remains a problem. The cost of improvement has constrained the ability to roll out a viable solution.

Silent Power was a Northern Powergrid project that was successful in installing a 40 kVA electrical energy storage system (EESS) into a standard sized fleet vehicle to restore power in the event of a network fault in place of a diesel generator. Although successful, this has limitations as a short-term solution rather than an enduring solution for worst served customers.

Scalability and Target Implementation Date
A successful solution should enable rollout across rural-type networks across Great Britain within a short timeframe. Implementation of options within RIIO-ED2 Control Period.

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Problem Statement Title
EIP028 - Are there whole-building solutions to decarbonise MOBs?

Problem Statement Details
Currently, decarbonisation of multi-occupancy buildings (MOBs) is completed in an uncoordinated approach that benefits individual early adopters, utilising solutions optimised for single premises marketed directly to the customer. Often this results in unnecessary costs associated with multiple site visits and assessment work for the Distribution Network Operator (DNO) for individual flats in the same building when they choose to decarbonise. In some cases, solutions require connection supply upgrades, which becomes a fairness issue for the residents who are slower to decarbonise, as spare capacity to the building no longer exists – prohibiting or delaying decarbonisation.

While the focus of the challenge is on decarbonisation and retrofitting existing buildings, challenges in decarbonisation for new builds should also be considered. Namely, large developments that stretch over multiple construction phases have changing demands and spatial restrictions that constrain network extension and supply upgrades.

A whole-building solution is required to support decarbonisation at a reduced price point and ensure network constraints are less likely to prohibit uptake of low carbon technologies (LCTs) for multi-occupancy building residents.

Key Stakeholders
Distribution Network Operators – interested in minimising the number of connection requests and avoiding or deferring network reinforcement where possible to lower overall costs.

Gas Distribution Networks – interested in providing low carbon and hydrogen infrastructure as part of heat decarbonisation.

Multi-occupancy building residents – interested in low carbon technologies and heat solutions including fairness of costs associated with solution implementation.

Building network operators – interested in identifying a clear route to building decarbonisation and their role in operation/maintenance of related assets behind the intake position.

Mainstream providers of whole-building solutions – interested in marketing all or part of heat decarbonisation services and solutions to the building owners, residents and/or building network operators.

Local authorities – interested in providing insight on prior projects into multi-occupancy building archetypes and applicable heat solutions, customer segments, stakeholders, and route to market challenges.

Building owners (incl. housing associations and residents management company) – interested in identifying a clear purchasing and ownership structure for building residents as well as roles and responsibilities to install and maintain the solution.

Developers – interested in adopting a whole-building heat decarbonisation solution in plans for future multi-occupancy building projects.

Target Market
An estimated 4.7 million residents of multi-occupancy buildings (buildings with more than four properties) across England within the RIIO-ED2 price control period.

Enablers and Constraints
NeatHeat looks at Zero Emission Boilers (ZEB) as an alternative LCT solution to gas boilers where heat pump installations are impractical or not cost-effective; the aim is to allow heat decarbonisation without triggering a network reinforcement for homes fitted with a 100 A fuse. This assumes the ZEB draws 40 A and is smart controlled to only operate at night (off-peak) – the assumption holds even if the home is fitted with an electric vehicle charge-point that typically draws 30 A. However, the solution is directly marketed to the consumer and does not address the challenges of an uncoordinated approach and the impact on incoming building supplies.

Heat Pump Ready Programme provided by BEIS is a funding stream that assists in optimised deployment of heat pumps through innovative solutions and methodologies.

An internal working group has been created within UK Power Networks to recognise and determine areas of focus around the increased complexity in LCT connection requests from multi-occupancy residents.

Scalability and Target Implementation Date
The solution would need to be scaled to the different building archetypes where applicable.

Roll-out would reach across all network regions and across urban and town areas.

Implementation date is flexible within the RIIO-ED2 period depending on the solutions proposed and level of readiness.

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Problem Statement Title
EIP062 - Can we maintain reliability for full electrification?

Problem Statement Details
A fully electrified future would reduce the number of energy vectors from three (gas, diesel and electricity) to just one (electricity alone) – naturally, this means a reduction in the reliability of the energy supply to the customer. Customers will not buy into a lower-reliability energy lifestyle, and this will hinder decarbonisation unless addressed.

Key Stakeholders
Energy users; broader society.

Target Market
30,000,000 users / 65,000,000 people.

Enablers and Constraints
Resilient storage projects, heat networks, self-generation / self-energy production, Ofgem IIS regime, Network-centric thinking.

Scalability and Target Implementation Date
Required ASAP, however roll-out timescales will depend on solution type and the roll-out logistics that imposes. Similarly for scalability.

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Problem Statement Title
EIP063 - How can we balance renewable supply/demand?

Problem Statement Details
The energy system must balance supply and demand 24/7/365. In relative terms, energy supply is far more abundant in the summer, with demand more abundant in the winter (utilisation issue).
Sizing the energy system to winter use will lead it massive underutilisation in the summer; sizing the energy system to summer use will lead a lack of energy in the winter.

Key Stakeholders
Energy users, generators/energy production, energy storage, energy transportation, energy retailers.

Target Market
30,000,000 users - size of market varies by solution.

Enablers and Constraints
Where storage is proposed, charge, discharge and self-discharge rates must be appropriate.
Any solution should also, wherever possible:

• Be as resilient to storms as the gas system is today.
• Increase the number of effective energy vectors.
• Be technically effective and financially efficient.
•  Be socially acceptable, acceptably safe and logistically feasible (inc. during delivery).

Scalability and Target Implementation Date
Assuming a methane boiler ban from 2025 (TBC) a solution will be needed by 2030 at the latest. Roll-out timescales will depend on the solution type and the roll-out logistics that imposes - similarly for scalability.

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