Future Energy Networks

Through consultation with the biomethane industry National Gas are looking to offer a cost effective, repeatable and simplified Minimum Connection arrangement at greenfield locations with low visual impact by locating the network isolation valves in a pit. Thus, avoiding a traditional larger Above Ground Installation with perimeter security fence and internal vehicle access and potential local authority planning permission.

The use of pits to house valves on National Gas AGI’s has historically created operational and maintenance issues, such as pipe pit wall transition corrosion, pit flooding and access restrictions.

However, through consultation with NG Chief Engineer a decision support paper was submitted and approved allowing the development of a valve pit arrangement to align with requests from the biomethane industry and address historic issues.

Following this decision, conceptual designs were completed for minimum connections at Oulton Airfield and Manby projects in 2024. These designs included a concept design of a MOC valve arrangement in a pit.

The Stopple technology is a flow stop tool essential for major projects and emergency works across the LTS and NTS gas network. Its capability was tested in 100% hydrogen within a helinite environment, in line with LTS Futures parameters as phase 1. This project focuses on validating flow-stopping technology as an additional deliverable with LTS Futures live hydrogen trial on the Granton to Grangemouth pipeline as a welded tee and hot-tapping operations is already being carried out. The trial will confirm the Stopple train’s effectiveness as a double-block and bleed solution for a 100% hydrogen system which will be available for the UK Gas Network. The findings will provide critical insights into the safe and efficient operation of the hydrogen networks supporting the transition from natural gas to hydrogen.

The Sustainable Vehicle Transport project assessed the feasibility of using biomethane-derived compressed natural gas (bio-CNG) as a lower-carbon transport fuel for operational vehicle fleets, while also considering the future potential for hydrogen refuelling infrastructure. The project examined viable locations for a pilot refuelling facility, reviewed available refuelling technologies and delivery models, assessed vehicle suitability, evaluated economic performance, and developed a roadmap for potential future deployment.

The study concluded that a bio-CNG trial is technically feasible and can provide substantial greenhouse gas emissions reductions, particularly in vehicle segments where electrification remains challenging due to range, payload, or onboard power requirements. The work also demonstrated that mature refuelling technologies and commercial delivery models already exist in the market, reducing technical implementation risk.

A key finding was that project viability is influenced less by technology readiness and more by practical considerations such as fuel demand, utilisation rates, planning requirements, land availability, and utility connections. The project therefore provided a structured evidence base to inform future investment decisions and potential progression to site-specific feasibility assessments and detailed business case development.

This project will investigate the potential impacts of district heating on the gas network, whether its viable for the network to support district heating and what repurposing would be required.

This project will assess the current and future role of gas distribution networks (GDNs) in supporting dispatchable electricity generation within a decarbonising UK energy system. It will identify method(s) for GDN operators to obtain accurate gas usage data from existing generation connections and develop future scenarios to inform network planning and investment.

The Welsh housing stock is particularly old. One third of homes were built before 1919. Just 10% were built in the last 18 years (Better Homes, Better Wales, Better World report commissioned by Welsh Government as of 2019), the older housing stock may reduce comfort for homeowners without increasing their energy demand.

This project will look to explore the opportunities that may be provided utilising gas hybrid solutions, and also looking to calculate the impact of such technologies on gas and electricity demand and subsequently how networks that feed the supplies can be operated in a flexible way to maximise network efficiency and support better whole systems thinking.

The statistical ‘value’ (i.e. risk reduction and cost) of remote hydrogen detectors has been determined through statistical based projects as part of the hydrogen heating programme (HHP). The cost has been shown to outweigh the risk, however, given hydrogen is not a mature heating solution, the cost can be justified in response to risk appetite from key stakeholders, such as consumers. This risk appetite is assumed. There is currently no analysis (qualitative or quantitative) into consumers attitudes towards the ‘value’ of remote detectors. This project will begin to explore the perception of risk reduction from remote detectors to be used to compliment the statistical based analysis to paint a fuller picture towards the utilisation and crucially, the value, of remote detectors.

To support the UK achieving net zero by 2050, there is a need to decarbonise the current gas networks of transmission and distribution levels. The conversion of the NTS into a hydrogen transmission network has been widely discussed and extensive work is underway to prove the technical capability and commercial viability of a 100% hydrogen network. There is also additional work to support the governments clean power targets and a three-molecule approach has been adopted within National Gas to consider (bio)methane, hydrogen (including hydrogen blends) and carbon dioxide.

The gas networks need to be prepared to operate and safely manage the transportation of all three molecules, especially with the ambition to develop a 100% hydrogen network in the future, upskilling and training the current workforce and the workforce of the future is a fundamental step to ensuring the facilitation of the energy transition.

Identifying the skills and competencies required both during the transition and after the transition to maintain the future systems was discovered in the Skills and Competencies NIA that closed in Q4 2023. A competency framework was developed that will provide a baseline for the training and resourcing strategy proposed for operational and technical skills and competency requirements for current and future workforces.

The project produced a comprehensive plan to identify the known gaps and to provide a roadmap for key developments of standards and policies which will drive the training and competency needs. Furthermore, it identified potential training facilities to support the development of the plan and ultimately facilitate rollout. The project also enabled a large-scale training and competency programme to be developed alongside the relevant technical standards and policies in readiness for deployment to the relevant engineers.

National Gas would therefore like to understand how AI tools can be used to accurately and efficiently produce training materials and create a more effective, personalised training experience.

National Gas Transmission are working to decarbonise the gas grid by transporting hydrogen rather than natural gas. Blending hydrogen with natural gas provides a stepping stone towards this goal, fostering the hydrogen economy whilst also benefiting from up to 7% carbon savings from a respective 20% hydrogen blend.

The UK government supports blending up to 20% hydrogen by volume into the gas distribution networks and there are ongoing trials and assessments into proving the safety and technical feasibility of hydrogen blending across all networks and pressure tiers in the UK. It is anticipated that initially a low percentage hydrogen blend will be accepted onto the National Transmission System with this potentially increasing up to 20% hydrogen blends being accepted. This is largely due to few modifications being required to accommodate low hydrogen blend percentages on the NTS.

Additionally, NTS level hydrogen blending is likely to develop in phases of hydrogen blend percentage entering the network due to the hydrogen supply in the UK developing gradually over time. 2% hydrogen on the NTS equates to approximately 5TWh of hydrogen production, therefore increasing this percentage will require time.

Variability in the gas blends of the network is likely due to the production of hydrogen gradually increasing over time and injection of that hydrogen being geographically spread across the network. There is also potential that hydrogen supply can vary based on factors such as production methods, direct demand off takers, and availability. Therefore, it is important to understand the implications of blended hydrogen and natural gas at variable levels between 0-5% hydrogen and 0-20% hydrogen blend.

Hydrogen blend variability encompasses a range of factors that need to be carefully managed to ensure a successful transition to a hydrogen-integrated energy system. Understanding the impact to stakeholders such as current customers and interconnecting countries will be crucial to successfully transitioning to a blended network and identifying ways to mitigate any risks and make sure National Gas are aligned to support our stakeholders needs where possible. There is also a need to evidence the impacts and any associated changes to risks from a whole system management perspective, and to research the impact of blend variability on compressor train machinery assets.