Net zero and the energy system transition

The consultant will deliver a report with supporting data to demonstrate that the economics stack up for biomethane while also supporting the UK’s net zero ambitions and contributing to our energy security.

This project involves a comprehensive set of tasks aimed at implementing and validating a domestic safety system for hydrogen use including excess flow valves.

This project will help WWU to understand considerations for 100% Hydrogen Rollout at a town scale to inform future activity on preparation for repurposing. Areas will be chosen which are representative of different networks housing stock and demographics which will require different approaches and engagement.

In 2022 a consortium of Urenco EDF the UK Atomic Energy Authority and Bristol University were awarded £7.7m worth of funding from the UK Government Department for Business Energy & Industrial Strategy (BEIS) to develop a hydrogen storage solution HyDUS. This solution could help to alleviate storage across GB. Unlike conventional storage approaches that rely on salt caverns or depleted fields HYDUS uses modular metal hydride technology enabling above ground deployment in geologically constrained areas.

This project will evaluate the feasibility and value of deploying HyDUS a modular above-ground hydrogen storage system as a means of storage across GB. The project will use WWU’s proposed HyLine hydrogen transmission corridor in Wales and South West England as a case study.

This project will undertake testing on technology for distributed production of low carbon hydrogen from natural gas biogas or other short chain hydrocarbons from waste. Which uses 90% less electricity than electrolysis of water and with 68% lower total energy costs.

The project will support early movers and convert gas from our network into a low carbon hydrogen solution. The compact and modular deployment of the technology enables hydrogen production systems to be installed directly at the energy user’s site. These systems convert grid-supplied natural gas to hydrogen on demand eliminating the need for additional infrastructure or on-site hydrogen storage and leaves the rest of the network unaffected

Repurposing of natural gas pipelines made of carbon steel for use with hydrogen blends requires a fitness-for-service analysis as part of the hydrogen use safety case. Girth welds of an unknown quality exist in the Local Transmission System (LTS). In hydrogen service these welds would have a greater susceptibility to fracture failure due to material embrittlement caused by interaction of steel material with hydrogen.

Current inspection methods do not routinely inspect girth welds for defects. Deterministic defect assessment models require the use of conservative assumptions for defect sizes material properties and loading. This can lead to overly pessimistic conclusions about the suitability of pipelines with girth welds for use with hydrogen.

More detailed probability-based assessments are required to reduce the inherent pessimism in deterministic calculation methods. This would provide confidence of the safety and allow for greater use of the LTS with hydrogen and contribute to a quicker and cheaper energy transition for the UK gas network.

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.

Following the work completed on the policies and procedures project by QEMS WWU have identified the requirement to update and re-vamp the existing Safe control of operations (SCO) procedures used by the network to support delivery of upcoming projects.

The LTS Futures project aims to understand how the local transmission system (LTS) could be repurposed from Natural Gas to hydrogen. The project encompasses several elements which will feed into a blueprint methodology for repurposing the LTS to hydrogen. During one of the work elements LTS Futures conducted full-scale testing of pipeline defects and small-bore connections exposed to hydrogen. Testing was conducted until failure to provide information for hydrogen pipeline design standards and operational procedures. This project will undertake further detailed analysis of the fracture surfaces to provide a visual confirmation of hydrogen diffusion into the pipeline microstructure and if this contributed to failure.

To maintain their above ground and underground pipework assets all Gas Distribution Networks (GDN) operate substantial fleets of commercial vehicles (primarily vans but also HGVs) together with mobile plant and powered equipment. Presently there is a complete reliance on hydrocarbon fuels primarily diesel and petrol. Both fuel types are usually sourced via the public retail forecourt network. Similar issues exist for other utility providers that operate underground and overground infrastructure.

Wales & West Utilities is undertaking a major programme of change to support decarbonisation and deliver a hydrogen-ready Net Zero gas network. Our distribution network iron mains replacement programme (Repex) requires significant excavation and pipe replacement activity laying long-life hydrogen-ready polyethylene pipe by a variety of means.

The project endeavours to identify a suite of suitable zero-emission mobile plant assets tools and equipment for carrying out Repex work that WWU could hire or purchase for operational trials and to identify opportunities for changing equipment items to simplify recharging/refuelling requirements in the future.

The objectives of this project are:

1. To analyse current energy demands sound pressure and vibration levels associated with existing ICE powered mobile plant assets ICE-powered tools and equipment and electrical equipment used for carrying out planned iron mains replacement work on the gas distribution network.
2. To estimate the future electrical energy demands (and sound pressure and vibration levels) placed by future zero-emission powered tools and equipment on a zero-emission site-based power generation facility.
3. To identify opportunities for changing equipment items to simplify recharging/refuelling requirements in future.
4. To identify a suite of suitable zero-emission mobile plant assets tools and equipment that WWU could hire (or purchase) and utilise for operational trials short and longer term. This will include the energy source and the means of recharging and/or refuelling on site and/or at regional depot locations.

The PE Service Pipe disconnection development project aims to produce a product and technique which can safely successfully and efficiently disconnect PE Service Pipes from an external Emergency Control Valve (ECV) following meter removal. This solution aims to prevent the inconvenience risks and additional costs associated with traditional excavation methods.

Novel green molecules have the potential to make a significant contribution to the decarbonisation of the UK’s gas network while also reducing system costs. Synthetic and e-methane can play a significant role in meeting future industrial demand as well as decarbonising the power transport and domestic heat sectors. This project investigates novel green gases in more depth to understand how they can be implemented effectively and quickly deployed to decarbonise the gas sector in the UK.

This study will assess the current scale and maturity of Bio-LNG production across GB and Europe to understand the market’s readiness for wider deployment. This includes identifying the economic technical and regulatory barriers that could limit progress and evaluating where suitable biomethane is available for liquefaction along with cost benefit analysis.

SGN operate four remote mainland Statutory Independent Undertakings supplied by tankered LNG from the Isle of Grain. The role of Bio-LNG in supporting network resilience and influencing decarbonisation pathways will be examined. Finally the economic viability of different operating models to determine the most effective route for future Bio-LNG development. Ultimately this study will inform a strategic decision on SIU decarbonisation options and inform potential for future Bio-LNG ‘islands’ across GB networks as a means of decarbonising.

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.

The work will develop a pathway for the biomethane sector to monetise CO2 and identify the role the gas networks can play reducing the long-term cost of gas decarbonisation.

The project focuses on exploring practical and innovative pathways for CO₂ utilisation with the goal of supporting scalable and cost-effective carbon management solutions. It examines a range of technologies market mechanisms and regional integration opportunities to better understand how captured CO₂ can be effectively reused. A key emphasis is placed on evaluating the economic feasibility of utilisation particularly through methanation including the potential commercial value of CO₂ and e-methane. The study combines technical and economic analysis with a case study of a methanation plant while also assessing local CO₂ markets and potential sales opportunities. The project also addresses key risks such as technology uncertainty hydrogen pricing and market volatility. Overall it aims to de-risk investment and stimulate the development of the CO₂ utilisation market from the AD sector.

This study assesses the available pathways to recover and monetise the biogenic CO₂ stream produced during biogas upgrading at UK anaerobic digestion (AD) plants with a particular focus on using it to produce synthetic natural gas (SNG). The study begins with extensive stakeholder and technology vendor engagement to identify suitable CO₂ sources potential utilisation pathways market opportunities and technology options.

A central element of the study is the development of a detailed methanation case study based on the capture of approximately 500 Nm³/h of biogenic CO₂ and the conversion of this CO₂ into e-methane using low-carbon hydrogen. Feasibility-level engineering will be completed for both the carbon capture and methanation facilities including process modelling mass and energy balances block flow diagrams preliminary process flow diagrams equipment sizing site layouts and Class 5 capital cost estimates supported by vendor data. These engineering outputs will underpin a detailed economic assessment examining the impact of key variables such as hydrogen cost electricity prices CO₂ value carbon credits and certificate revenues on the levelized cost of e-methane production. The study also includes a local CO₂ market assessment a review of by-product utilisation opportunities such as reaction water and waste heat recovery and the development of a roadmap outlining the steps.

Early cluster projects will not benefit I&C customers that are located away from industrial clusters and are traditionally more distributed in nature. These customers are unlikely to have access to hydrogen infrastructure developed through the primary industrial clusters. This presents the need for an alternative solution.

This project will explore the concept of how a larger number of low-volume hydrogen producers can support I&C customers in the absence of natural ‘clustering’ and high-volume production by using the South West region of WWU’s network as a case study. This will be done by exploring the whole systems concept of a gas network which is driven by distributed green hydrogen production at strategic locations where there is access to both gas and electricity grid infrastructure.

FutureGrid CO2 is the final phase of a suite of Carbon Dioxide projects looking at how National Gas can repurpose parts of its network to transport gaseous-phase Carbon Dioxide safely. What started out as literature reviews and feasibility studies will turn into physical testing and demonstration. National Gas will be using its world-leading FutureGrid facility to demonstrate how Carbon Dioxide will flow through its pipes delivering on its promise to further use this facility after our successful FutureGrid SIF Beta projects. We will also be completing carbon dioxide venting ruptures and real-time impurity corrosion tests- all of which are underexplored.

As the UK attempts to decarbonise residential heat to meet net zero by 2050 electric heat pumps along with heat networks are expected to play a key role. However it is generally accepted that no one technology will be able to meet the needs of all households. If we are to deliver affordable low- carbon heating in the residential sector we shall need as wide a range of technology options as possible to overcome the economic and technical challenges facing every customer.

Project GaIN (Gathering Insights) will explore alternatives to heat pumps and heat networks which can utilise the robust gas network and benefit from its current upgrade programme supporting the aims of DESNZ’s decarbonisation of heat roadmap. The project will discover and assess additional technology options where alternative solutions might be more costly or difficult to deliver; this will include LAEP system benefits as well as localised CAPEX and OPEX costs.

UK’s Net Zero Emissions Target and the Role of Hydrogen: The UK has committed to a legally binding net zero emissions target by 2050. Achieving this target necessitates the integration of hydrogen particularly in hard-to-decarbonize industrial applications and peaking power generation. The recent publication of the Climate Change Committee’s Seventh Carbon Budget highlights hydrogen’s significant role within the electricity supply sector. Hydrogen is identified as a crucial source of long-term storable energy that can be dispatched as needed and as a feedstock for synthetic fuels. For hydrogen to fully contribute to a future hydrogen system its production storage and transportation must be considered collectively.

East Coast Hydrogen (ECH) Project: In recent years Cadent in partnership with National Gas and Northern Gas Networks (NGN) has developed the East Coast Hydrogen (ECH) Project. The ECH project aims to decarbonize primarily industry and power sectors. As part of this initiative Cadent has developed the East Midlands Hydrogen Pipeline (EMHP) which aims to connect hydrogen production at Uniper’s Ratcliffe on Soar site to major industrial and power off-takers in the East Midlands. The project seeks to transport hydrogen to major population centres including Nottingham Leicester Melton Mowbray Derby and Burton upon Trent. During the development of the EMHP it became evident that hydrogen storage plays a critical role in establishing a resilient and efficient hydrogen system. Consequently a consortium was formed to explore the feasibility of storage leading to the East Midlands Storage Project (EMSTOR).

Discovery Phase of EMSTOR: During the Discovery Phase EMSTOR evaluated various technologies for large-scale hydrogen storage in the East Midlands. The technologies considered included lined rock caverns lined rock shafts silos and geological storage options such as aquifers and disused hydrocarbon fields. After comparing these technologies against several technical parameters including Technology Readiness Level (TRL) cost size and location relative to pipelines it was determined that hydrogen storage in geological fields particularly disused hydrocarbon fields is the most viable option. Therefore disused hydrocarbon fields in geological formations were selected for further consideration in the Alpha Phase.

Alpha Phase Consortium: To execute the Alpha Phase a consortium led by Cadent and including Star Energy Ltd Centrica Energy Storage National Grid British Geological Society University of Edinburgh and Uniper was established. This consortium will focus on advancing the feasibility and implementation of hydrogen storage in disused hydrocarbon fields.

This project concerns the research into welding residual stress values and the effect that they have on the overall pipework repurposing assessment route described in relevant hydrogen standards. Currently overly conservative values need to be applied for welding residual stresses in any repurposing assessment. This project aims to build evidence on actual and modelled residual stresses seen within the pipelines industries with a focus on natural gas pipelines. As the welding residual stress is a critical aspect of the fracture mechanics assessment any improvements which can be gained would have an overall positive impact on the assessment results.

Biomethane from Anaerobic Digestion is currently injected into Gas Distribution Networks as a renewable alternative to fossil-fuel based natural gas.

AD plants currently supply largely constant flows whilst gas demand fluctuates daily and seasonally creating supply-demand imbalances which increase system balancing requirements.

Flexible locally produced biomethane could help GDNs manage system balance by increasing injection during demand peaks or cold spells.

This project will use biomethanisation injecting hydrogen to convert additional CO₂ within digesters to boost biomethane output dynamically supporting network balancing and Net-Zero ambitions.

Operational and regulatory frameworks will also be assessed to enable wider adoption of dynamic injection.

The UK gas networks are undergoing a major transition to support the integration of green gases including biomethane and hydrogen. A significant challenge is the inability of the current design modelling. Cadent’s current modelling relies on outdated assumptions and lacks the granular real-time demand insight needed for modern decarbonising gas networks. Existing tools cannot capture intra-day demand variability below-7-bar network complexity or the growing impact of biomethane injections—creating risks in planning operational decisions and reinforcement strategy.

RTN addresses these challenges by delivering accurate weather-adjusted consumer-level demand modelling and integrated analysis across pressure tiers. This enhances forecasting improves biomethane integration and strengthens model validation and operational control. In the future state RTN provides Cadent with a modern data-rich and automated modelling capability that reduces unnecessary reinforcement improves customer outcomes supports the energy transition and lays the foundation for potential future use in peak-demand modelling and regulatory engagement.

This programme is leveraging the data and learning from historic projects to develop a range of novel network modelling tools that will enable bio gas designs to be informed consumer focused and optimised for localised conditions and demands.

IGEM have received requests from operators to update the hydrogen TD1 / TD13 supplements to take account of outputs from research projects. The project will review and assess the updates required based on findings from completed hydrogen research projects. This will support the repurposing of existing pipelines and installations from Natural Gas to hydrogen and Natural Gas/hydrogen blends with input and support from users/stakeholders and formal approval by IGEM.

The project will also develop a methodology for fracture and fatigue assessments for existing Natural Gas pipelines to be repurposed to hydrogen service. This methodology will assess the impact of blends of hydrogen up to and including 100% hydrogen to determine whether pipeline derating and/or deblending is required. The requirements for the application of this specification should be included in the updates to the IGEM/TD/1 and IGEM/TD/13 hydrogen supplements.

The Fairer Warmth Hub (FWH) connects stakeholders of the Net Zero Transition through place-based strategies providing tools and guidance to facilitate local energy plans and enhance collaboration. The FWH integrates digital tools and community engagement to facilitate effective communication and planning among diverse stakeholders including households small businesses schools social healthcare and local authorities. FWH is designed to bridge the gap in the energy transition by providing tailored support to these stakeholders ensuring that the transition is inclusive and just. The FWH integrates three core elements:

• Trained ‘Champions’ – Volunteers or staff known as Champions are recruited and trained to support community engagement helping to build trust and reduce miscommunication in local energy initiatives.
• Digital Tools (Virtual Assets) – Innovative digital tools (App + Website) and resources are used to facilitate energy transition planning and community engagement particularly assisting Customer In Vulnerable Situation (CIVS) and those who are digitally excluded.
• Community Centres (Non-Virtual Assets) – Physical community hubs serve as accessible locations for hands-on support providing a space for CIVS and other stakeholders to engage directly in the energy transition.