Projects

National gas pipeline systems rely heavily on protective coatings and cathodic protection to prevent corrosion and ensure long-term integrity. Coatings act as the primary barrier against environmental exposure while cathodic protection—typically using sacrificial anodes or impressed current systems—supplements this by mitigating electrochemical reactions that cause metal degradation. The introduction of hydrogen into these pipelines as part of decarbonization efforts presents new challenges. Hydrogen can permeate coatings and accelerate corrosion processes especially in the presence of certain microbes. Microbiologically induced corrosion (MIC) driven by bacteria such as sulphate-reducing bacteria (SRB) can be exacerbated by hydrogen which some microbes use as an energy source. This interaction may compromise both the coating and cathodic protection systems necessitating advanced materials and monitoring strategies to maintain pipeline safety and performance in a hydrogen-integrated future.

The HIRSA programme is assessing ignition risks for the transition to hydrogen with Stage 3 focusing on high pressure static risks including shockwave ignition and rapid adiabatic compression. This research supports the safe integration of hydrogen into gas networks.

This project will identify and evaluate current technology available for pipes suitable for use in natural gas blended gas and hydrogen gas networks operating above 7 bar.

This project will see QEM Solutions conduct a comprehensive literature review of market reports on pipes used in high-pressure gas systems as well as of existing options for transportation of high-pressure gas in industrial uses with transferrable learnings. QEMS will develop a matrix comparing pros and cons of each solution and consolidate the findings into a final project report.

The project will facilitate the energy system transition by investigating the available and most optimal pipeline materials for natural gas blended gas and hydrogen gas networks above 7 bar considering all operational capex requirements and full lifecycle costs. This work is important for informing investment decisions in pipeline replacement materials addressing a gap in current knowledge.

As the energy system transitions away from unabated natural gas and parts of the gas network are either decommissioned or repurposed to support the UK’s net zero goals there is an increased risk of unintentional third-party damage to the network. Any supply interruptions to the transmission network would directly impact security of supply across the country and have a significant cost to customers including power generators industry and domestic users. This project will investigate the benefits of moving from expensive low frequency manual network inspections to innovative AI assisted surveillance technologies in combination with satellite imagery and drones.

This project will develop network and/or entry site solutions that will enable biomethane supply to meet the swings in demand through the year.

This project will focus on barholing operations conducted after an emergency gas escape within the H100 Fife Distribution Network Operations. The scope will consider H100 scenarios specifically the establishment of a new distribution network to deliver Hydrogen to selected properties in the conversion area. The minimum pressure for the H100 Fife Distribution network is 27 mbar and the maximum pressure is 75 mbar. The aim of this project is to provide further evidence to support SGN operations on the H100 distribution network during emergencies and any future trials or broader rollouts of Hydrogen.

Steer Energy has been identified as a suitable contractor for executing this project due to their extensive expertise in this field and their previous work on the Barhole Trials and ITL Haldane Drill Isolator project. Steer has a proven partnership with SGN and the wider gas industry offering a variety of services including experimental lab testing training and testing facilities.

This project aims to address major gaps identified in NIA2_SGN0078 which conducted a thorough literature review of the international scientific and industry knowledge base. The work will focus on characterising the hydrogen permeability rate of API Grades X52 and X60 vintage pipelines and welds by analysing the microstructure of each sample investigating the impact of internal corrosion layers and conducting mechanical testing post-exposure.

A correlation exercise will also be conducted to equate gaseous charging with electrochemical charging. The outcome of this work targets an improved industry best-practice for permeation and fracture toughness tests providing a validated benchmark framework with the potential to inform future updates of industry standards and procedures and saving costs on any future material and permeation testing work.

This project has been initiated to assess the technical and commercial feasibility of direct hydrogen injection into the gas distribution network at 5% and 20% by volume. It supports the broader Market Frameworks appraisal by providing the evidence needed to evaluate whether both System Entry Models direct injection and pre-blending are feasible under varying network conditions.

The need for this study was identified through the Hydrogen Blending Implementation Plan which outlined two technical approaches for hydrogen connections: injecting hydrogen directly into the network or pre-blending it before entry each with distinct technical and commercial implications. While National Gas has assessed both models for the transmission network a gap analysis revealed that these findings are not directly transferable to the distribution network.

Evidence for pre-blending was previously completed as part of HyDeploy and the Hydrogen Blending Functional Specification project. It was shown that this approach provides more controlled mixing but may require more complex infrastructure leading to higher costs for the producer. Although it is assumed Direct Injection may be achievable at lower cost there are multiple key technical challenges associated with the technique such as the potential for inadequate hydrogen mixing which could result in non-compliant gas safety concerns including material integrity and operational constraints e.g. GSMR exclusion zones.

Through literature review CFD modelling engineering assessments and commercial analysis the study will evaluate the technical and safety performance risks and cost implications of direct injection across a range of scenarios and configurations.

Clean Power 2030 (CP2030) aims for a fully decarbonised electricity system using unabated gas only as backup. This introduces an important challenge: how can the gas transmission network remain viable and deliver flexibility during extreme demand events despite not being utilised most of the time? This project aims to understand how to sustain the gas network technically and economically in a low average high peak demand future focusing on the interaction between gas and electricity systems.

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.

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 Innovation Highway phase 2 project will utilise AI and machine-learning to optimise the full innovation value chain. The platform will develop a minimum commercial product to help facilitate collaboration amongst networks and other sectors such as water companies so they can innovate together. AI-empowered algorithms will simplify the identification mapping assessment and selection of problems and ideas reducing manual processing time and enhancing effective decision making; this will support identifying and prioritising projects that will deliver the highest benefits. The platform will also help networks automate the development of cost benefit analysis.

NGN use various systems with each one requiring different levels of human interaction. The drive towards net zero will involve the introduction of a multi-gas network increasing the network’s complexity. It’s envisaged there’ll be an additional amount of human interaction required to support the systems resulting in staff having to spend less time on strategic initiatives and operational challenges. The control room needs to be future ready to improve productivity and operational efficiency hence the necessity for additional interactions to support the various systems mentioned below.

• SCADA
• Business applications
• Electronic logging system

Alongside the EIC we have completed the ‘Call for Innovation’ process and identified a supplier to deliver a feasibility study to identify vendors offering platform technology for: Automation Enhancement of situational awareness.

This project will produce valuable insights into understanding the relationship between human behaviours and the utilisation of safety devices with automated functionality. This follows the work done on hydrogen risk mitigations which included technology such as hydrogen detectors with automated functionality to remotely notify the emergency call centre to dispatch an engineer to the detected leak. In their review of this work HSE have asked if the assumption that consumers will continue to act the same knowing the device will be doing some automated will change the validity of the modelling assumptions. This project will address that query and build on our own understanding of consumer insights; something which could add a depth of value to other projects exploring automated safety systems.

Following completion of Phase 2 of the H21 Hydrogen Ready Components project this project will look to extend the methodology developed under this project to encompass the assessment of assets operating above 7 barg. The assessment tool will be incorporated into the LTS Futures blueprint methodology for repurposing existing Natural Gas transmission assets to hydrogen. The scope will include transmission assets above 7 barg and up to the maximum transmission pressure of 94 barg and will focus on the conversion to 100% hydrogen. Assets in scope will cover both above and below ground assets and include bends valves regulators slam shuts relief valves and pig traps. Assets excluded include pipelines compressors and cast iron components.

This project will develop a hydrogen‑specific risk‑based gas escape classification system for WWU by reviewing existing standards and methodologies modelling hydrogen leak behaviour conducting field trials and developing a final operational tool and updated procedures. The project adapts natural gas escape management processes for use on 100% hydrogen networks by analysing gaps in current practice validating real‑world behaviour through targeted trials and producing training documentation and decision‑support tools.

Gas networks in Britain have connected 130 biomethane plants which together have capacity to produce over 11TWh of green gas – enough to meet the annual demand of around a million average homes.

As biomethane production tends to cluster in farming areas some parts of the country have higher connections and future potential. This can present challenges in relation to the capacity available for existing and new plants to inject biomethane especially when overall gas demand is lower in summer months.

The gas networks and their partners have mature systems and processes to assess capacity and work with producers and developers to identify capacity. More recently potential solutions to constraints have been developed and trialled notably through the Optinet project (NIA_CAD0061) and including Wales & West Utilities’ Smart Pressure Control roll out and Reverse Compression.

The Government is continuing to support new production through the Green Gas Support Scheme and is considering future policy for biomethane. This could significantly increase the volume of biomethane produced and connected which has been recognised in NESO’s FES 2025.

In its Draft Determination for RIIO-3 Ofgem has recognised the potential for future growth in biomethane connections. The regulator “encourage[s] the GDNs to collectively engage with the biomethane industry to streamline and align connection processes”.

In response to this and other feedback from biomethane developers and operators this project will explore the potential for more standardised approaches to support capacity for biomethane and overcome constraints.

SGN Innovation is exploring how to support its operational colleagues in implementing tools and practices to mitigate emissions coming from pipeline operations. This work is driven by SGN’s GD3 Environmental Action Plan which sets a target to reduce operational carbon emissions by 46% relative to the 2019 baseline with a long-term target of net zero by 2045.

Whilst the Environmental Action Plan and the Network Asset Management Strategy articulate what SGN will invest in there be an “operational pathway” in how these ambitions translate into day-to-day operational decision-making as well as ensuring that the competing requirements on operational staff (efficiency vs emissions reduction for example) are addressed and appropriate guidance and prioritisation given.

This project creates a pragmatic approach to bridge the identified operational gap by establishing a decision framework and playbook for commissioning and decommissioning pipelines that embeds gas drawdown as a default activity with the potential if successful to expand to other areas of implementing the Environmental Action Plan. The aim is to enable SGN’s and other Network workforce to deliver consistent efficient emissions reductions across GD3.

This project constitutes a research study investigating the opportunities for gas network infrastructure to provide resilience solutions.

Organisations are becoming more reliant on electricity just as the grid decentralises driving a growing need for stronger resilience against power outages. High profile outages such as those seen around Heathrow Airport and across Spain and Portugal in 2025 have brought the need for additional resilience solutions sharply into focus.

By engaging end users DNOs and other stakeholders this programme will quantify the UK’s resilience challenge build the evidence base and determine whether there are opportunities for gas to play an additional role in providing resilience.

This project is a research and analysis desktop study to provide a clear evidence base for regulatory and strategic governance pathways related to multi-occupancy building (MOB) decarbonisation. By mapping legislation standards and regional constraints SGN will develop the building blocks for a decision-making framework to justify future investment and planning choices across various low-carbon technologies.

This project will investigate the effect of hydrogen exposure and conditioning on the failure behaviour of internal sharp defects in pipeline steels. The work builds on testing previously undertaken as part of the LTS Futures programme and NIA_SGN0070 where full-scale burst testing indicated that hydrogen exposure may influence the failure pressure associated with internal crack-like defects. However the available dataset remains limited and some results have shown inconsistencies suggesting that hydrogen conditioning and exposure history may significantly affect material response.

The project will undertake additional full-scale burst testing on vessels fabricated from representative pipeline material containing machined internal sharp defects. The vessels will be subjected to controlled hydrogen conditioning prior to burst testing to evaluate the effect of hydrogen diffusion and retention on fracture behaviour and failure pressure.

Complementary laboratory-scale mechanical testing and fractographic analysis will also be performed to characterise material properties and failure mechanisms. The results will support pipeline integrity assessments and the safe repurposing of the UK Local Transmission System (LTS) for hydrogen transport.

The OptiSTORE project seeks to address the challenge of supply and demand imbalance within Wales & West Utilities’ (WWU) network as means to mitigate the need for storage particularly in support of Net Zero ambitions including the planning for development of new hydrogen pipelines and WWU’s existing HyLine programme.. Current geological hydrogen storage methods such as salt caverns saline aquifers and depleted oil and gas reservoirs are capital intensive often technically complex and reliant on specific geological conditions which are less present across WWU’s geography.

Whilst hydrogen can be stored as a liquid this process requires extremely low temperatures which is technically complex and costly due to the energy required to maintain such low temperatures. One promising alternative to this is Ammonia which is attractive due to its lower storage temperature (-33°C versus -253°C for hydrogen) higher volumetric energy density and existing infrastructure and regulatory familiarity.

This project will explore the feasibility of using ammonia as a means to provide supply-side flexibility of hydrogen to support industrial clusters and future hydrogen pipeline developments.

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.

This project evaluates the rapidly developing Sustainable Aviation Fuel (SAF) sector and assesses the technical commercial regulatory and safety feasibility of repurposing existing gas pipelines to transport liquid aviation fuels. The uptake of SAF is critical to decarbonising the UK aviation industry and achieving net zero targets. To support the scale-up of SAF production and use the development of reliable affordable and low-carbon infrastructure is essential. Pipelines offer a cost-effective environmentally sustainable and high-capacity transport solution. The study aims to enable scalable SAF infrastructure while providing a productive long-term use for gas assets that are unlikely to be required for refurbishment or alternative repurposing.

This project constitutes a UK-wide strategic assessment of digestate production arising from projected biomethane growth including quantification of volumes in 2030 2040 and 2050 and analysis of nutrient composition (nitrogen phosphorus and potassium). Sustainable land-spreading capacity will be evaluated under current regulatory constraints with regional nutrient imbalances mapped. Export potential and post-processing technologies will be assessed to determine infrastructure needs and optimal management pathways. Findings will inform how digestate management can best support sustainable biomethane growth.