Net zero and the energy system transition

Develop credible and independently modelled pathways to test the economic case of developing a H₂ Backbone and prepare NGT for dialogue with NESO DESNZ HMT and a wider group of stakeholders.

The Unaccounted-for Gas (UAG) project aims to develop a predictive tool that identifies and quantifies UAG across the National Transmission System (NTS). Leveraging 12-18 months of SCADA data the tool will simulate gas flow and metering behaviour to pinpoint anomalies and reduce losses. UAG currently represents significant financial cost to the consumer; even a 1% reduction could yield practical savings. The project aligns with RIIO-2 NIA criteria and supports regulatory compliance under the Gas Transporter Licence Part J of Special Condition 5.6 (System operator external incentives revenues and costs) requiring National Gas to undertake work to investigate the causes of UAG. It builds on prior research and integrates learnings from international benchmarks. The initiative will enhance operational efficiency improve data transparency and support long-term decarbonisation goals through better system visibility and control.

Phase 1 of the project compiled a list of oils and greases considered to be gas-facing on the NTS along with identifying functional and material property requirements of these products. Proposed standards and testing methodologies were also outlined to inform the next phase of the project. In Phase 2 the project will proceed with additional required activities to ensure the safe utilisation of NTS oils/greases in a hydrogen pressurised environment. These activities include laboratory testing for lubricants and functional testing for sealants to assess degradation and performance of these products in hydrogen. Subsequently requirements for in-service monitoring will be identified.

The Phase 3 project on gas inhibitors for hydrogen pipelines aims to translate lab-scale findings into practical applications for the UK’s National Transmission System. It focuses on validating the effectiveness of oxygen and alternative inhibitors in mitigating hydrogen embrittlement addressing unresolved safety and integrity concerns from previous phases and designing a plan for safe integration into existing infrastructure. The project includes physical demonstration planning and network design to assess technology implementation.

Existing defect assessments and repair methodologies designed for natural gas service are aligned with the T/PM/P/** and T/PM/P/** management procedures and are adopted to inspect assess and repair pipelines for defects and take suitable measures to mitigate them. However the scope and applicability of the assessment inspection and repair techniques in the presence of high-pressure hydrogen remain uncertain. The key questions which form an outline of the project are:

1. What are the different types of defects we may encounter or consider injurious in the presence of hydrogen?
2. What is the impact of hydrogen on each defect type? Have the mechanisms of failure changed for each defect type after hydrogen-natural gas blending?
3. Will the existing repair techniques be applicable under transmission of high-pressure hydrogen and hydrogen-natural gas blends?
4. Can we implement the defect assessment inspection and repair methodologies safely? Are the techniques safe and suitable for the pipeline operations and maintenance teams?

The project seeks to answer the above in addition to understanding the types and extent of repairs across the NTS and assess the impact of hydrogen on the effectiveness of these inspection assessment and mitigation technologies.

This project will assess the application of Rising Pressure Reformer (RiPR) technology to produce a tuneable blend of biogenic methane and hydrogen supporting the decarbonisation of gas networks. The project will focus on the how control of the gas produced would fit with requirements for network injection and assessing locations for connection.

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.

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.