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Climate neutrality for the year 2050 is the goal assumed at the level of the EU27+UK. As Romania is no exception, it has assumed the gradual mitigation of pollution generated by the energy sector, and by 2030, according to 'Fit for 55', the share of energy from renewable sources must reach 42.5% from total energy consumption. For the rest of the energy produced from traditional sources, natural gas and/or coal, modern technologies will be used to retain the gaseous noxes. Even if they are not greenhouse gases, NO and SO2, generated from fossil fuel combustion, cause negative effects on the environment and biodiversity. The adsorption capacity of different materials, three nanomaterials developed in-house and three commercial adsorbents, both for NO and SO2, was tackled through gas chromatography, elemental analysis, and Fourier-transform infrared spectroscopy. Fe-BTC has proven to be an excellent material for separation efficiency and adsorption capacity under studied conditions, and is shown to be versatile both in the case of NO (80.00 cm3/g) and SO2 (63.07 cm3/g). All the developed nanomaterials generated superior results in comparison to the commercial adsorbents. The increase in pressure enhanced the performance of the absorption process, while temperature showed an opposite influence, by blocking the active centers on the surface. [ABSTRACT FROM AUTHOR]

Hydrogen is an emerging technology changing the context of heating with cleaner combustion than traditional fossil fuels. Studies indicate the potential to repurpose the existing natural gas infrastructure, offering consumers a sustainable, economically viable option in the future. The integration of hydrogen in combined heat and power systems could provide residential energy demand and reduce environmental emissions. However, the widespread adoption of hydrogen will face several challenges, such as carbon dioxide emissions from the current production methods and the need for infrastructure modification for transport and safety. Researchers indicated the viability of hydrogen in decarbonizing heat, while some studies also challenged its long-term role in the future of heating. In this paper, a comprehensive literature review is carried out by identifying the following key aspects, which could impact the conclusion on the overall role of hydrogen in heat decarbonization: (i) a holistic view of the energy system, considering factors such as renewable integration and system balancing; (ii) consumer-oriented approaches often overlook the broader benefits of hydrogen in emission reduction and grid stability; (iii) carbon capture and storage scalability is a key factor for large-scale production of low-emission blue hydrogen; (iv) technological improvements could increase the cost-effectiveness of hydrogen; (v) the role of hydrogen in enhancing resilience, especially during extreme weather conditions, raises the potential of hydrogen as a flexible asset in the energy infrastructure for future energy supply; and finally, when considering the UK as a basis case, (vi) incorporating factors such as the extensive gas network and unique climate conditions, necessitates specific strategies. [ABSTRACT FROM AUTHOR]

Transitioning from predominantly natural gas domestic heating to low carbon heating is one of the major challenges of the UK's net zero decarbonisation pathway. Compact wall-hung combination boilers are the dominant heating appliance and continue to be installed as a rate of over 1.5 million per year, compared to less than 50 k per year for Heat Pumps. The disparity persists despite repeated Government support in the form of the Renewable Heat Incentive and the Green Homes Grant. Compact hybrid appliances offer a technology solution similar to the current combination boiler in terms of size and performance, which could be attractive to consumers. However, there is currently little knowledge of the emissions savings that could be achieved in practice by compact hybrid appliances. This research systematically analyses real world high frequency boiler data to evaluate the potential of such appliances to make carbon savings while emulating combination boiler operation. By utilising high frequency diagnostic data from combination boilers, the disaggregated (hot water and heating) demand is mapped onto hybrid models to determine the energy and emission impact. Exploration of the relative power output of the HP and boiler components of the modelled hybrid appliances provides insight into the appropriate specification of compact hybrids which can deliver similar heat service to boilers while maximising emissions savings. The analysis shows that hybrid appliances with moderately sized HPs can significantly contribute to the decarbonisation of the homes considered in the study. Considerable disruption could be avoided in retrofit due to the physical size of the proposed heat pump and ability of the hybrid system to operate with the existing heat emitter network. [ABSTRACT FROM AUTHOR]

Future energy scenarios include both green and blue hydrogen, as both are needed to scale up decarbonized energy supply. A transition to renewable energy is predicted over time, but the urgency we are facing cannot be met by renewable energy alone. For blue hydrogen production, the overall greenhouse gas (GHG) emissions are primarily affected by emissions from natural gas production, processing, and transport (CO2 and methane), as well as process efficiency and carbon capture ratio. Few complete and updated analyses are available that cover the entire blue hydrogen value chain with the best available technology for process facilities, as well as the proper design, operation, and maintenance of all relevant systems and infrastructure. This paper analyses the GHG intensity of blue hydrogen, using recent data as well as input from technology providers on state‐of‐the‐art gas reforming technologies. Data are primarily based on natural gas production and transport in the North Sea Basin, with gas export from the Norwegian continental shelf to continental Europe or the United Kingdom, and with blue hydrogen production either in Norway or near pipeline landfall in the European Union or United Kingdom. Some data related to potential blue hydrogen production in the US Appalachian region are also given. The data show that the properly designed and operated value chains for blue hydrogen supply, with minimal emissions from natural gas supply and high carbon capture in hydrogen production, will give a major reduction in GHG emissions from energy end‐use. GHG footprint for end‐users based on blue hydrogen will typically be 80%–90% lower than for direct supply and use of natural gas. [ABSTRACT FROM AUTHOR]

The North Sea is one of the most studied and exploited ecosystems worldwide. The multiple uses from industrial, transport, as well as recreational activities have required researchers, regulators, and legislators to understand and, where possible, to minimize any expected negative environmental impacts. As with any international sea, assessing the current pressures and management actions resulting from these activities is centred on several national and international legislative instruments. This variety of co-existing legislations makes development processes and regulatory assessments cumbersome and time consuming. Hence there is a need to integrate environmental risk assessment and management across sectors, ensuring smart, cost-effective data generation, as well as supporting and standardizing environmental practices. This paper provides an overview of the changing regulatory frameworks regarding offshore chemicals used in the oil and gas industry, and the process of chemical risk assessment conducted under the Offshore Chemical Notification Scheme (ONCS) in the UK. Our view of methodological, research, and regulatory needs and challenges that should be addressed to ensure an adequate and sustainable assessment of offshore chemical use in the North Sea is discussed. Furthermore, we discuss the issues faced regarding chemicals used in the UK oil and gas sector with respect to declining hydrocarbon production. [ABSTRACT FROM AUTHOR]

Research to date has identified cost and lack of support from stakeholders as two key barriers to the development of a carbon dioxide capture and storage (CCS) industry that is capable of effectively mitigating climate change. This paper responds to these challenges through systematic evaluation of the research and development process for the Acorn CCS project, a project designed to develop a scalable, full-chain CCS project on the north-east coast of the UK. Through assessment of Acorn's publicly-available outputs, we identify strategies which may help to enhance the viability of early-stage CCS projects. Initial capital costs can be minimised by infrastructure re-use, particularly pipelines, and by re-use of data describing the subsurface acquired during oil and gas exploration activity. Also, development of the project in separate stages of activity (e.g. different phases of infrastructure re-use and investment into new infrastructure) enables cost reduction for future build-out phases. Additionally, engagement of regional-level policy makers may help to build stakeholder support by situating CCS within regional decarbonisation narratives. We argue that these insights may be translated to general objectives for any CCS project sharing similar characteristics such as legacy infrastructure, industrial clusters and an involved stakeholder-base that is engaged with the fossil fuel industry. • Cost reduction and stakeholder support are essential for CCS industry development. • Acorn is aimed to develop a full-chain CCS system at minimum cost by the 2020s. • Infrastructure re-use and staged investment and development enable cost reduction. • Stakeholder and local community engagement is key to promote a just transition. • The Acorn experience can be implemented in regions with similar CCS needs. [ABSTRACT FROM AUTHOR]

Current discourse on the transition to a decarbonized energy system future is dominated by renewable energy solutions. Initial conditions for this transition may vary across different regions and countries. There are, however, also opportunities for innovative solutions that utilize other low‐carbon energy sources and technology mix. Sustainable development is a contested concept and varies with priorities attached to social, economic, and environmental goals. Therefore, the one‐size‐fits‐all type of solution paradigm needs to be broadened, to accelerate action in the short to medium term. Our argument is that natural gas can be an important complementary transition fuel to support renewable energy in the short‐ and medium‐term transition phases. This means that the goal of zero fossil fuel as a short‐ and medium‐term solution needs to be reconsidered. This takes us to the next argument that innovation and upgraded technology in the low‐carbon fossil fuel sector will provide an important impetus for low‐carbon transition, which we see as a phase lasting until the middle of the century. However, the transition toward a sustainable energy future of gas‐fueled solutions has challenges from the social, technical, economic, geographical, and political points of view. Suitable local solutions should, however, also be assessed. These should take into consideration infrastructure, local demands, resources, and economic aspects as well as national energy policies. An analysis based on the experiences of four countries, both developed and developing, is presented in this study. The countries selected for this study can be placed in two categories: those with an abundance of natural gas reserves (Iran and Norway) and those that are import‐dependent (India and UK). The cross‐country analysis will help us to understand the realistic challenges and opportunities of natural gas as a transition fuel. [ABSTRACT FROM AUTHOR]

The UK is in the early stages of developing a shale gas industry and to date six test wells have been drilled but none yet exploited commercially. Some argue that shale gas could reduce energy prices and improve national energy security. However, the costs of bringing commercial-size wells into operation are uncertain and the impact shale gas could have on the UK energy market is currently unknown. Therefore, this paper evaluates the economic viability of developing a UK shale gas industry and the impacts it could have on the UK gas and electricity markets and consumer energy bills up to 2030. The estimated life cycle (levelised) costs of shale gas production range from 0.47 to 56.74 pence/MJ (0.61–73 US$ cents/MJ), with an average value of 4.64 pence/MJ. The break-even price at which shale gas can be sold varies between 0.95 and 114.44 pence/MJ, averaging at 9.47 pence/MJ, depending on the volume of gas produced by a shale gas well. The latter is two times higher than imported liquefied natural gas, around 30% more expensive than UK natural gas and three times greater than the price of US shale gas. Electricity from shale gas is on average 17% more expensive than from domestic conventional gas but still more competitive than most other electricity options, including coal and renewables. However, the impact of shale gas on the energy market would be limited across the expected range of shale gas penetration into the gas and electricity mixes, suggesting that it would have little effect on energy prices. This is reflected in an almost negligible impact on consumer energy bills. The potential of shale gas to boost the UK economy is also limited, contributing 0.017–0.033% to the GDP. This is an order of magnitude lower than the contribution of US shale gas to its GDP (0.2%), indicating that the economic success of shale gas in the US may not be replicated in the UK. These findings will be of interest to shale gas developers and policy makers not only in the UK but in other countries considering exploitation of shale gas resources. [ABSTRACT FROM AUTHOR]

Continuous, high frequency in situ observations of ethane and propane began in the United Kingdom in 1993 and have continued through to the present day at a range of kerbside, urban background and rural locations. Whilst other monitored C 2 – C 8 hydrocarbons have shown dramatic declines in concentrations by close to or over an order of magnitude, ethane and propane levels have remained at or close to their 1993 values. Urban ethane sources appear to be dominated by natural gas leakage. Background levels of ethane associated with long range transport are rising. However, natural gas leakage is not the sole source of urban propane. Oil and gas operations lead to elevated propane levels in urban centres when important refinery operations are located nearby. Weekend versus weekday average diurnal curves for ethane and propane at an urban background site in London show the importance of natural gas leakage for both ethane and propane, and road traffic sources for propane. The road traffic source of propane was tentatively identified as arising from petrol-engined motor vehicle refuelling and showed a strong downwards trend at the long-running urban background and rural sites. The natural gas leakage source of ethane and propane in the observations exhibits an upwards trend whereas that in the UK emission inventory trends downwards. Also, inventory emissions for natural gas leakage appeared to be significantly underestimated compared with the observations. In addition, the observed ethane to propane ratio found here for natural gas leakage strongly disagreed with the inventory ratio. [ABSTRACT FROM AUTHOR]

When natural gas prices are subject to periodic decoupling from oil prices, for instance due to peak-load pricing, conventional linear models of price dynamics such as the Vector Error Correction Model (VECM) can lead to erroneous inferences about the nature of cointegration relationships, price adjustments and relative values. We propose the use of regime-switching models to address these issues. Our regime switching model uses price data to infer whether pricing is oil-driven (integrated) or gas-specific (decoupled). We find that UK natural gas (NBP) and oil (Brent) are cointegrated for the majority of the sample considered (1997-2014). UK gas prices tend to decouple during fall and early winter, when they increase relative to oil consistent with seasonal demand for natural gas creating gas-specific pricing. When evidence favors integrated markets, we find that the industry 10-1 rule-of-thumb holds (the value of one MMbtu of natural gas in the UK market is one tenth the value of one barrel of Brent oil), while the overall relationship, including decoupling periods, is 9.2-1. The paper highlights that what relative value to use, depends on the purpose of its use. [ABSTRACT FROM AUTHOR]

There is at present much interest in unconventional sources of natural gas, especially in shale gas which is obtained by hydraulic fracturing, or ‘fracking’. Boreholes are drilled and then lined with steel tubes so that a mixture of water and sand with small quantities of chemicals – the fracking fluid – can be pumped into them at very high pressure. The sand grains that wedge into the cracks induced in the shale rock by a ‘perforating gun’ then releases gas which returns up the tubes. In the United Kingdom (UK) exploratory drilling is at an early stage, with licences being issued to drill a limited number of test boreholes around the country. However, such activities are already meeting community resistance and controversy. Like all energy technologies it exhibits unwanted ‘side-effects’; these simply differ in their level of severity between the various options. Shale gas may make, for example, a contribution to attaining the UK’s statutory ‘greenhouse gas’ emissions targets, but only if appropriate and robust regulations are enforced. The benefits and disadvantages of shale gas fracking are therefore discussed in order to illustrate a ‘balance sheet’ approach. It is also argued that it is desirable to bring together experts from a range of disciplines in order to carry out energy technology assessments. That should draw on and interact with national and local stakeholders: ‘actors’ both large and small. Community engagement in a genuinely participative process – where the government is prepared to change course in response to the evidence and public opinion – will consequently be critically important for the adoption of any new energy option that might meet the needs of a low carbon future. [ABSTRACT FROM AUTHOR]

Abstract: Airborne fine particulate matter (PM2.5) has been collected at two sites in the West Midlands conurbation, UK, representing urban background and rural locations. Chemical analyses have been carried out for major anions, trace metals, total OC and EC, and for individual organic marker species including n-alkanes, hopanes, PAHs, organic acids and sterols. Source apportionment has been conducted using both a pragmatic mass closure model and the US EPA chemical mass balance (CMB) model. The pragmatic mass closure model is well able to account for the measured PM2.5 mass in terms of chemical/source components, and the chemical mass balance model has been used to apportion the carbonaceous component of the aerosol. The dominant components of PM2.5 at both sites are secondary inorganic (sulphate and nitrate) and carbonaceous particles. The CMB model shows the latter to arise mainly from road traffic sources, with smaller contributions from vegetative detritus, wood smoke, natural gas, coal, and dust/soil. The CMB model also identifies an important component of the organic aerosol not associated with these primary sources, which correlates very strongly with secondary organic aerosol estimated from the OC/EC ratio. The split between different automotive source types does not relate well to UK emission inventories, and may indicate that CMB source profiles from North American studies and different carbon analysis protocols may lead to erroneous conclusions. [Copyright &y& Elsevier]

The European natural gas market is characterized by declining indigenous resources, particularly in the UK and the Netherlands, and a growing dependence on a small number of large exporters who, as a consequence, see their market power increasing. In this paper we analyze long-run scenarios for the European natural gas markets in a model, NATGAS, that explicitly includes both factors, resource constraints and producers' market power. Finite resources lead to interdependencies of current production decisions and future opportunities. These decisions in turn depend on the potential for large producers to set market prices above marginal costs. We analyze the impact of conditions on the global LNG market on market shares of pipeline gas suppliers, as well as on the speed of depletion of indigenous European resources. We focus on how shadow prices of resource constraints affect substitution patterns in the various scenarios. [ABSTRACT FROM AUTHOR]

In the UK, AFC Energy has entered into a binding Heads of Agreement deal with HiiROC Ltd, whose plasma-based technology has proven its ability to extract hydrogen from methane and biomethane – readily available from incumbent gas networks – without CO 2 or other greenhouse gas emissions. The 'green' hydrogen produced using this technique could in turn fuel AFC's H-Power™ alkaline fuel cell systems, thereby opening up methane as a candidate carrier of green hydrogen for low-cost power generation. [ABSTRACT FROM AUTHOR]

Abstract: Approximately, hourly C2–C7 hydrocarbon concentrations from gas chromatographic measurements are reported for an urban background site in Birmingham, UK, from summer 1999 and winter 1999–2000. Comparison with another measurement site suggests that the observed behaviour is typical of the urban background in the whole conurbation. The lack of any correlation between seasonal variation and OH rate coefficient shows that hydrocarbon concentrations are dominated by local sources. Chemical mass balance techniques have been applied and indicate the main sources are vehicle emissions (exhaust and fugitive) and natural gas leakage. Winter concentrations of isoprene correlate well with butadiene concentrations suggesting an automotive related source. This correlation disappears during the summer when isoprene displays a high correlation with radiation. During a period of the summer campaign ethane and propane concentrations displayed a regular diurnal behaviour, which has been utilized to estimate the ratios of the day/night boundary layer height and natural gas emission rates for the West Midlands conurbation. [Copyright &y& Elsevier]

The urgency of climate change, while the world economy is projected to depend on fossil fuels for some time, requires substantial reduction of greenhouse gas emissions in the oil and gas industry. This study proposes a methodology for the decarbonisation of offshore natural gas production networks through progressive electrification, either by connecting offshore platforms with nearby renewable energy sources, e.g. offshore wind farms, or by sharing resources so as to improve their energy generation efficiency. In this context, a novel multi-objective mixed-integer linear programming model is proposed to simultaneously minimise greenhouse gas emissions and associated costs from a determined offshore platform network, considering technical constraints, such as maintaining the energy balance of the network, ensuring that cables are installed to enable energy flows, and respecting the maximum generation capacities and minimum operating loads of turbines. For demonstration purposes, the proposed methodology was applied to a UK Southern North Sea network and optimised using the augmented ε -constraint method. The Pareto front approximation obtained suggests that the studied network's cumulative greenhouse gas emissions can be reduced by 25% over the next 10 years at an average cost of US$370.9 per tonne CO 2 e. This study also explores the impact that uncertainties and postponing investment decisions may have in the set context. [Display omitted] • Offshore natural gas production GHG emissions can be reduced via electrification. • Energy generation options were analysed using a multi-objective optimisation model. • Sharing power production reduces GHG emissions in mature offshore fields in the UK. • GHG emissions reduction (25%) is achieved at average cost of US$370.9/tonneCO 2 e. • Integration with offshore wind farms provided the greatest benefits in the optima. [ABSTRACT FROM AUTHOR]

Decarbonising heavy-duty trucks is challenging due to high journey power and energy requirements. With a growing fleet of commercial vehicles in the UK, biomethane can provide significant reductions in greenhouse gas (GHG) emissions compared to fossil diesel. Methane is a potent GHG with a global warming potential (GWP) of 23–36, therefore reducing levels in the atmosphere can have a significant impact on climate change. There are a range of anthropogenic sources of methane that could be collected and processed to provide sustainable energy (upcycled), e.g., agricultural waste and the waste water system. This paper explores the impact of using upcycled methane in transport in South East England, evaluating local sources of anthropogenic methane and the environmental and economic impact of its use for a heavy-duty truck compared to fossil and battery electric alternatives. Analysis concludes that the use of upcycled methane in transport can provide significant reductions in lifecycle GHG emissions compared to diesel, fossil natural gas or battery electric trucks, and give net negative GHG emissions where avoided environmental methane emissions are considered. Furthermore, upcycling solutions can offer a lower cost route to GHG reduction compared to electrification. [ABSTRACT FROM AUTHOR]

Norwegian energy giant Equinor is leading a project to develop one of the UK's first large-scale facilities to produce hydrogen from natural gas in combination with carbon capture and storage (CCS), i.e. 'blue' hydrogen. The Hydrogen to Humber Saltend (H2H Saltend) project kicks off the beginnings of a decarbonised industrial cluster in the Humber region, the UK's largest cluster by industrial emissions. [ABSTRACT FROM AUTHOR]

The first pilot project in the UK to inject zero-carbon hydrogen into a natural gas network to heat homes and businesses is now fully operational. HyDeploy is a ground-breaking 'green' energy trial at Keele University in Staffordshire that could help the UK cut its carbon emissions and open the door to a low-carbon hydrogen economy. [ABSTRACT FROM AUTHOR]

Salt rock has demonstrated to be an effective seal trapping hydrocarbon reservoirs in geological structures for millions of years. It has favourable properties to act as an underground leakproof storage container thanks to its low permeability, plastic behaviour (creep), self-healing (damage recovery) properties, and high thermal conductivity. Natural Gas and hydrogen can be stored in underground salt caverns and be extracted to supply power generation in certain moments of the day or during specific periods of the year to meet peak demand in the electricity grid. Linked to gas injection and withdrawal periods, salt caverns are subjected to cyclic temperature and pressure fluctuations related with the type of storage gas or cavern usage. Salt rock, which mainly consists of halite, can contain solid solution impurities and second phase content, such as anhydrite, gypsum, clay and other minerals. Previous studies have shown that this salt rock composition affects its rheological behaviour and physical properties. The presence of these different minerals in the salt rock formation can result in a rock that is more prone to crack and microcrack development. The effect of second phase content in salt rock under cyclic temperature and pressure conditions still needs to be better constrained. A total of ten samples of natural salt rock with varying second phase content from Boulby Mine have been geochemically analysed and tested under a set of cyclic thermo- mechanical conditions for 48h. Three different cyclic thermo-mechanical scenarios were tested simulating the depth of the main salt caverns in the UK. The samples were tested under cyclic thermo-mechanical triaxial conditions with axial compression cycles between 4.5 and 7.5 MPa, at a rate of 0.5 MPa/s for a total of 48h, and adapting the confining pressure and test temperature to the three depth scenarios. For the scenario of shallow salt cavern (depth of 200- 500 m), two tests were performed at same confining pressure of 12 MPa and two different temperatures, one at 25ºC and then 55ºC. The other two scenarios were middle depth (800- 1200 m), tested at 25 MPa and 25ºC and 55ºC, and deep depth (1500- 2000 m), tested at 45 MPa confining pressure and 55ºC and 75ºC. After the mechanical tests, a microstructural analysis is performed in order to study the different rheological behaviour of the rock components and the resulting microstructures.The chemical analysis from the natural samples indicated a main composition of halite (between 85-90%, depending on the sample) with some anhydrite (around 5- 10%) and a low content of kieserite and carnallite (around 3- 5% maximum in total depending on the sample) only in some samples as impurities. During the cyclic thermo-mechanical tests, major deformation is observed in the initial stages of the test and a more uniform deformation after completion of the first cycles. Different initial stiffness is observed to be related to second phase content in the salt rock. Microstructural analysis of the samples after the deformation test allowed identifying the main deformation boundary structures between minerals with different rheology. [ABSTRACT FROM AUTHOR]

Natural gas is regarded as a cleaner alternative to other fossil fuels with respect to pollution and carbon dioxide (CO2) emissions when burned as fuel. Methane (CH4) is a potent greenhouse gas however and can escape during natural gas production and transmission. It is therefore vital to quantify fugitive CH4 emissions from natural gas production and transmission when assessing its contribution to climate change. Identifying and distinguishing emission sources is an important step in quantifying emissions, with δ13C in CH4, ethane:methane (C2H6:CH4) and CH4:CO2 ratios being well used as signatures for this. Principally, these signatures enable fugitive natural gas emissions to be distinguished from other CH4 sources in aircraft and ground sampling. Studying these signatures also has potential utility in identifying specific emission processes (e.g. flaring vs leaking gas) and further characterising specific sources (e.g. maturity or depth of gas source). As part of the United Nations Climate and Clean Air Coalition (UN CCAC) international methane studies, a five-day aircraft campaign was conducted over gas rigs in the southern North Sea in April 2018, with a further four-day campaign scheduled for April/May 2019. Flights are conducted using the British Antarctic Survey (BAS) Twin Otter aircraft. C2H6, CH4 and CO2 mole fractions are measured continuously during flights using cavity enhanced spectroscopy. Whole air samples are collected in flasks and bags when flying through emission plumes at low altitude and analysed in the laboratory for δ13C in CH4 using high precision CF-GC-IRMS. Emissions from a few rigs have been identified from the April 2018 campaign, with enriched δ13C in CH4 signatures or elevated C2H6 measured from the CH4 plumes, indicating the rigs as sources. Targeted sampling in the April/May 2019 flight campaign should enable testing of the temporal consistency of the emissions and their δ13C in CH4 and C2H6:CH4 signatures, and aid investigation of the relationship between these signatures, and infrastructure and gas source characteristics.Two ground surveys have also been conducted around each of three gas terminals on the UK's east coast. Surveys were conducted by car and on foot, again using cavity enhanced spectroscopy for continuous in situ C2H6, CH4 and CO2 mole fraction measurement, and whole air sample collection in bags for laboratory analysis of δ13C in CH4. Differences in excess CH4 from terminals have been detected. δ13C in CH4 and C2H6:CH4 signatures of gas terminal emissions have been compared with those for gas rigs sampled during the aircraft campaigns, and additionally, with signatures from UK gas distribution network leaks. [ABSTRACT FROM AUTHOR]

In the UK, ITM Power is supplying a 0.5 MW electrolyser to the HyDeploy consortium, as part of a programme to demonstrate the use of blended hydrogen in the natural gas grid. [ABSTRACT FROM AUTHOR]

In the UK, Ceres Power has begun commercial field trials of its wall-mounted combined heat and power (CHP) product in occupied homes. The residential CHP systems utilize Ceres Power''s unique intermediate-temperature solid oxide fuel cell technology running on natural gas. [Copyright &y& Elsevier]