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There is widespread recognition of the need for new homes to feature only low or zero-carbon (LZC) heating. However, residential developers continue to choose conventional high-carbon options such as natural gas boilers over net-zero compatible alternatives. This study explores how UK local authorities (LAs) within the English planning systemcan encourage residential developers to deploy LZC heating systems within their projects. We adopt an embedded case study design and analyse 30 residential project proposals within two LA areas. Our study examines local planning policies and interactions between developers and LA officers, along with the resultant outcomes, through documentary analysis and expert interviews with local stakeholders. We find that LAs can encourage developers to adopt LZC heating technologies above and beyond what is required nationally. The conditions for this to occur are (1) a planning policy which restricts allowable heating technology options, (2) empowering LA officers to enforce policies, (3) advice and support for developers to consider alternatives, and where necessary, (4) political backing to challenge unwilling developers. Study findings highlight the important role of LAs in creating the conditions for the transition to LZC heating, which show how they can use powers within the planning system to encourage developers to make low carbon choices without the need for direct investment. [ABSTRACT FROM AUTHOR]

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]

The UK government aims to transition its modern natural gas infrastructure towards Hydrogen by 2035. Since hydrogen is a much lighter gas than methane, it is important to understand the change in parameters when transporting it. While most modern work in this topic looks at the transport of hydrogen-methane mixtures, this work focuses on pure hydrogen transport. The aim of this paper is to highlight the change in gas distribution parameters when natural gas is replaced by hydrogen in the existing infrastructure. This study uses analytical models and computational models to compare the flow of hydrogen and methane in a pipe based on pressure loss. The Darcy-Weisbach and Colebrook-White equations were used for the analytical models, and the k- ε model was used for the computational approach. The variables considered in the comparison were the pipe material (X52 Steel and MDPE) and pipe diameters (0.01m–1m). It was observed that hydrogen had to be transported 250–270% the velocity of methane to replicate flow for a fixed length of pipe. Furthermore, it was noted that MDPE pipes has 2–31% lower pressure losses compared to X52 steel for all diameters when transporting hydrogen at a high velocity. Lastly, it was noted that the analytical model and computational model were in agreement with 1–5% error in their findings. [Display omitted] • Hydrogen is expected to replace methane by 2035 for domestic heating applications. • Analytical and computational models were used to compare flow of hydrogen and methane. • Hydrogen velocity must be up to 2.7 times faster than methane to replicate flow. • MDPE pipes showed lower pressure losses than steel pipes due to reduced roughness. [ABSTRACT FROM AUTHOR]

Ambient concentrations of 22 volatile organic compounds (VOCs) measured at London Marylebone Road (LMR), an urban traffic site, and London Eltham (LE), an urban background site, were analyzed over a period of 23 years (1997–2019) to assess the impact of pollution control strategies. A significant decrease in ambient concentration is seen for the majority of VOCs analyzed with total VOC burden decreasing by 76% and 59% for LMR and LE, respectively, across the period studied. This is likely as a result of legislative controls. This analysis was extended to consider the dominant contribution of VOCs to ozone formation at the sites utilizing photochemical ozone creation potential (POCP) values. Similarly, the overall reactivity of the VOC burden at the sites has resulted in a significant decrease of 11% and 7% per year in ozone formation potential (OFP) for LMR and LE, respectively. At LMR, the declines in OFP for VOCs associated with road traffic emissions are all in good agreement at 11%–13% decrease per year. Reasonable agreement is also seen at LE with a decrease of 6%–11% per year in OFP of the VOCs related to traffic sources. VOCs related to non‐traffic sources, namely ethane and propane from natural gas leakage, did not see a significant decline over the study period at either site. The variation and composition of the overall VOC burden was compared across three decadal time periods (1997–2000, 2001–2010, 2011–2019) and saw an increase in significance of these pollutants at both sites. At LMR, ethane and propane moved from the fifth and eleventh largest contributors to total VOC burden in 1997–2000 to the first and second largest contributors in 2011–2019. At LE, a similar trend is seen with ethane and propane becoming the first and second largest contributors in the most recent time period, up from second and eighth at the beginning of the dataset. The similarity between these sites suggests such pollutants are not sufficiently controlled under current legislation. The increase in significance of ethane and propane was mirrored in their contribution to ozone generation potential at both sites but ethene continues to dominate in contribution to OFP. At LMR, ethene dominates by a factor of 4 and 5 compared with ethane and propane, respectively, however, at LE, ethene dominates to a lesser extent over ethane and propane at factors of 1 and 3, respectively. Alkanes are typically considered to be less important in the context of OFP due to their low reactivity in comparison to other VOCs. Analysis presented herein demonstrates the negative impact of ignoring such emissions as their influence begins to grow such that alkanes now represent 3 of the 5 highest contributors to tropospheric ozone formation at both sites (in order of contribution at LMR: ethene > propene > n‐butane > ethane > propane; and LE: ethene > ethane > n‐butane > propane > propene). The importance of high‐quality gas‐phase kinetic studies to determine the impact of VOCs in ozone production is clear and the usefulness of metrics such as POCPs is demonstrated. [ABSTRACT FROM AUTHOR]

This study examines the inner dynamics of multifractality between the carbon market (EU ETS) and four major fossil fuel energy markets: Brent Crude Oil (BRN), Richards Bay Coal (RBC), UK Natural Gas (NGH2), and FTSE350 electricity index (FTSE350) from January 04, 2016, to March 04, 2022. First, we decompose the daily price changes by applying seasonal and trend decomposition using loess (STL). Then, we examine the inner dynamics of multifractality and cross-correlation by employing multifractal detrended fluctuation analysis (MFDFA) and multifractal detrended cross-correlation analysis (MFDCCA) using the remaining components of the return series. Our findings reveal that all series and the cross-correlations of carbon and fossil fuels markets have multifractal characteristics. We find crude oil to be the most efficient market (lowest multifractal), while coal is the least efficient (highest multifractal). Only coal shows persistent, whereas the other markets exhibit antipersistent behavior. Interestingly, the coal and EU ETS pair demonstrates a higher degree of multifractal patterns. In contrast, the pair of natural gas and EU ETS exhibits the lowest multifractal characteristics among the energy markets. Only the crude oil market shows persistent cross-correlations in the multifractality. These findings have important academic and managerial implications for investors and policymakers. [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]

In the debate on the decarbonisation of heat, renewable electricity tends to play a much more dominant role than green gases, despite the potential advantages of gas in terms of utilising existing transportation networks and end-use appliances. Informed comparisons are hampered by information asymmetry; the renewable electricity has seen a huge grid level deployment whereas low-carbon hydrogen or bio-methane have been limited to some small, stand-alone trials. This paper explores the regulatory and commercial challenges of implementing the first UK neighbourhood level 100% low-carbon hydrogen demonstration project. We draw on existing literature and action research to identify the key practical barriers currently hindering the ability of strategically important actors to accelerate the substitution of natural gas with low carbon hydrogen in local gas networks. This paper adds much needed contextual depth to existing generic and theoretical understandings of low-carbon hydrogen for heat transition feasibility. The learnings from pilot projects, about the exclusion of hydrogen calorific value from the Local Distribution Zone calorific value calculation, Special Purpose Vehicle companies, holding of liability and future costs to consumers, need to be quickly transferred into resilient operational practice, or gas repurposing projects will continue to be less desirable than electrification using existing regulations, and with more rapid delivery. • This paper explores barriers for the first UK 100% hydrogen distribution project. • Learnings from pilot projects need to be transferred into UK operational practice. • Existing regulations present barriers to gas distribution innovation projects. [ABSTRACT FROM AUTHOR]

The results of a survey in the reconnaissance mode of large prospecting blocks, local areas and hydrogen degassing zones in Great Britain are presented. Experimental studies were carried out with the aim of additional approbation of direct-prospecting methods and improvement the methodology of their application in exploration process for oil, gas natural hydrogen and living water, as well as the deep structure of Earth structural elements studying. The investigations have been conducted with using the mobile and low-cost technology, that include modified methods of frequency-resonance processing and decoding of satellite and photo images, vertical electric-resonance sounding of a cross-section, as well as a method of integrated assessment of the prospects of oil and gas potential of large prospecting blocks and license areas. The developed super-mobile direct-prospecting technology has provided the authors with a unique opportunity to conduct a huge number of experiments in various regions of the globe. In the process of experimental work conducting, numerous evidence was obtained in favor of the deep (abiogenic) genesis of hydrocarbons in the framework of the concept of hydrogen degassing of the Earth. The proven technology allows filling the studied cross-section with specific rocks (sedimentary, metamorphic and magmatic), as well as identifying areas on the surface and intervals in the cross-section that are promising for ore and combustible minerals prospecting. The super-mobile methods can be used to assess the prospects for oil and gas (ore) potential of large exploration blocks and local areas (including those put up for auction), to select the optimal locations (sites) for laying exploration and production wells, assessment of the prospects for discovering oil and gas deposits in the deep and super-deep horizons of crosssection, prospecting and localization of zones with deep channels location, through which the chemical elements, fluids and mineral matter migrate into the upper horizons of cross-section. [ABSTRACT FROM AUTHOR]

There is a growing consensus that the distribution system operator (DSO) role is changing, given the implications of net zero. The transition process requires additional roles for the DSO in facilitating the new technologies and business models that will contribute to decarbonization. Although discussions on the active DSO abound, a working definition is still missing. This paper proposes a working definition and a methodology for measuring the extent to which a DSO is active. The methodology will be applied to electricity and natural gas DSOs in the UK, and the challenges will be presented and analyzed. • The roles of Distribution System Operators (DSOs) due to increasing penetration of variable renewable sources, additional electrification of consumption, gas decarbonization, decentralization, and energy storage. • The active DSO facilitates new processes, technologies and business models required for system decarbonization. • Measuring the extent to which the DSO is active will enable policymakers and regulators to evaluate the current and future role of DSOs. • The dimensions for measuring the active DSO are transport, heating, flexibility and Distributed Energy Resources (DER) integration, adaptive indicative planning, and innovation. • Based on limited data, the United Kingdom electricity DSOs are most active on flexibility and DER integration , while gas DSOs are most active on the decarbonization of heating. [ABSTRACT FROM AUTHOR]

Top-down greenhouse gas measurements can be used to independently assess the accuracy of bottom-up emission estimates. We report atmospheric methane (CH 4) mole fractions and δ13 CH 4 measurements from Imperial College London from early 2018 onwards using a Picarro G2201-i analyser. Measurements from March 2018 to October 2020 were compared to simulations of CH 4 mole fractions and δ13 CH 4 produced using the NAME (Numerical Atmospheric-dispersion Modelling Environment) dispersion model coupled with the UK National Atmospheric Emissions Inventory, UK NAEI, and a global inventory, the Emissions Database for Global Atmospheric Research (EDGAR), with model spatial resolutions of ∼ 2, ∼ 10, and ∼ 25 km. Simulation–measurement comparisons are used to evaluate London emissions and the source apportionment in the global (EDGAR) and UK national (NAEI) emission inventories. Observed mole fractions were underestimated by 30 %–35 % in the NAEI simulations. In contrast, a good correspondence between observations and EDGAR simulations was seen. There was no correlation between the measured and simulated δ13 CH 4 values for either NAEI or EDGAR, however, suggesting the inventories' sectoral attributions are incorrect. On average, natural gas sources accounted for 20 %–28 % of the above background CH 4 in the NAEI simulations and only 6 %–9 % in the EDGAR simulations. In contrast, nearly 84 % of isotopic source values calculated by Keeling plot analysis (using measurement data from the afternoon) of individual pollution events were higher than - 45 ‰, suggesting the primary CH 4 sources in London are actually natural gas leaks. The simulation–observation comparison of CH 4 mole fractions suggests that total emissions in London are much higher than the NAEI estimate (0.04 Tg CH 4 yr -1) but close to, or slightly lower than, the EDGAR estimate (0.10 Tg CH 4 yr -1). However, the simulation–observation comparison of δ13 CH 4 and the Keeling plot results indicate that emissions due to natural gas leaks in London are being underestimated in both the UK NAEI and EDGAR. [ABSTRACT FROM AUTHOR]

Summary: This paper sheds light on the causality linkages between economic growth and energy production, that is, natural gas, bioenergy and waste, coal, nuclear, petroleum, wind, solar and hydro for the United Kingdom over the period 1998Q1 to 2017Q4. To this end, we apply time‐domain causality tests—Toda‐Yamamoto causality test and gradual shift causality test, and frequency domain causality (FDC) test for empirical analysis to sort out the causality among the outlined variables under consideration. Empirical findings from the spectral BC causality test reveal that (a) changes in energy production from natural gas and petroleum spur significant changes in economic growth in the United Kingdom; (b) economic growth causes energy production from natural gas, petroleum, wind, solar, hydro and nuclear and (c) it is worthy of mentioning that time and FDC tests provide consistent outcomes at different significance and frequency levels. On the causality analysis, the hypothesis that natural gas triggers economic growth is valid, while the result also reveals a feedback causality the variables of concern. Similarly, economic growth drives nuclear energy production one‐way as well as total energy drives economic growth. These results provide policy implications for energy and environmental sustainability in the United Kingdom where renewable energy sources drive economic growth. Thus, necessitates the need to maintain the current trajectory for more renewable energy promotion in energy mix relative to fossil‐fuel energy sources. Highlights: Economic impact is revisited for the United Kingdom over the period 1998Q1 to 2017Q4.Toda‐Yamamoto, gradual shift and frequency domain causality tests were employed.Distinct roles of natural gas, fossil, nuclear and mix of renewables were explored.Changes in natural gas and petroleum significantly spur economic growth.Frequency domain causality tests offer consistent time and frequency changes. [ABSTRACT FROM AUTHOR]

The first applications of hydrogen in a natural gas grid will be the admixing of low concentrations in an existing distribution grid. For easy quality and process control, it is essential to monitor the hydrogen concentration in real time, preferably using cost effective monitoring solutions. In this paper, we introduce the use of a platinum based hydrogen sensor that can accurately (at 0.1 vol%) and reversibly monitor the concentration of hydrogen in a carrier gas. This carrier gas, that can be nitrogen, methane or natural gas, has no influence on the accuracy of the hydrogen detection. The hydrogen sensor consists of an interdigitated electrode on a chip coated with a platinum nanocomposite layer that interacts with the gas. This chip can be easily added to a gas sensor for natural gas and biogas that was already developed in previous research. Just by the addition of an extra chip, we extended the applicability of the natural gas sensor to hydrogen admixing. The feasibility of the sensor was demonstrated in our own (TNO) laboratory, and at a field test location of the HyDeploy program at Keele University in the U.K. [Display omitted] • A platinum based hydrogen sensor was developed showing full reversibility. • It operated at room temperature without any hysteresis. • Hydrogen detection in natural gas was demonstrated between 0.1 and 30 vol%. • The hydrogen sensor can be easily combined with a full gas composition sensor. [ABSTRACT FROM AUTHOR]

Hydrogen has a potentially important future role as a replacement for natural gas in the domestic sector in a zero-carbon economy for heating homes and cooking. To assess this potential, an understanding is required of the global warming potentials (GWPs) of methane and hydrogen and of the leakage rates of the natural gas distribution system and that of a hydrogen system that would replace it. The GWPs of methane and hydrogen were estimated using a global chemistry-transport model as 29.2 ± 8 and 3.3 ± 1.4, respectively, over a 100-year time horizon. The current natural gas leakage rates from the distribution system have been estimated for the UK by the ethane tracer method to be about 0.64 Tg CH 4 /year (2.3%) and for the US by literature review to be of the order of 0.69–2.9 Tg CH 4 /year (0.5–2.1%). On this basis, with the inclusion of carbon dioxide emissions from combustion, replacing natural gas with green hydrogen in the domestic sectors of both countries should reduce substantially the global warming consequences of domestic sector energy use both in the UK and in the US, provided care is taken to reduce hydrogen leakage to a minimum. A perfectly sealed zero-carbon green hydrogen distribution system would save the entire 76 million tonnes CO 2 equivalent per year in the UK. • Natural gas leakage from UK and US domestic sectors are estimated. • UK domestic leakage is estimated to be 0.64 Tg CH 4 /year (2.3% of consumption). • Using hydrogen in the domestic sector should reduce global warming. • A UK green hydrogen distribution system could save up to 76 million tonnes CO 2 e per year. • Leakage from a future hydrogen economy should be controlled and minimised. [ABSTRACT FROM AUTHOR]

Decarbonising the residential heating and cooking sector is essential to meet national and international carbon emission reduction targets. Hydrogen has been identified by the scientific community, industry, and policy makers as part of the solution to this challenge. Hydrogen has been used for decades in many industries, formerly making up approximately 50% of the Town Gas used for heating and cooking in UK homes in the mid 20th century. It is now crucial to ensure safety regulations are met, and public acceptance gained, before hydrogen can start being used for residential heating. Demonstration projects require hydrogen distribution networks to be odorised. This study examines the use of sulphur-based odorants, which are currently in use in the UK and Europe to odorise Natural Gas, to be used in a 100% hydrogen gas demonstration network in the UK. We undertook a comparative testing programme to evaluate the escape detection properties of odorised hydrogen against odorised methane and natural gas. This comparative approach will help address the question asked by UK and EU regulators: is hydrogen 'as safe as' natural gas? The results show that untrained participants can identify an escaping gas odorised with Odorant New Blend and standby odorant 2, in hydrogen, natural gas or methane, at the regulatory threshold of 1% gas in air. These results contribute to the safety-case of H100 led by SGN. • Odorant NB and THT in hydrogen, methane and natural gas (NG) are compared. • The odorants tested with hydrogen allow for detection of gas escapes similar to NG. • The comparative methodology aligns with the UK's Health and Safety Executive policy. • The findings can support the development of hydrogen demonstration projects. [ABSTRACT FROM AUTHOR]

• Develops an institutionalist framework for analysing heat transition governance. • Political institutions, political economy and degree of centralisation play key roles. • Compares the governance of heat transitions in the Netherlands and the UK. • The Netherlands is taking a consensus-building approach led by local government. • The UK government is taking a more centralised market-led approach. • There are emerging differences across the devolved governments within the UK. Decarbonising residential heat is essential for achieving net zero targets. The Netherlands and the UK are embarking on heat transitions from similar starting points, with a heavy dependence on natural gas. However, their governance approaches differ, with local municipal visions and plans playing a lead role in the Netherlands compared with a market-led approach in England and Wales. Scotland occupies an intermediate position. This article focuses on why these differences have arisen through the development of a comparative institutionalist framework. We show that heat transition governance approaches are rooted in institutional arrangements for politics, political economy and the degree of centralisation. Our framework can be applied to heat transition governance approaches more widely, but it is not aimed at evaluating different approaches and an agenda for further research would be to link governance effectiveness to institutional context. [ABSTRACT FROM AUTHOR]

Clumped-isotope analysis provides new constraints on the formation and evolution of methane. High-resolution isotope-ratio mass spectrometry (HR-IRMS) is a sensitive, precise, and stable analytical technique increasingly used in methane clumped-isotope analysis. However, the lack of standard reference frames hinders the comparison of data from different laboratories and the evaluation of accuracy. In this study, an absolute reference frame was introduced for HR-IRMS analysis of the multiply substituted methane isotopologues 13CH 3 D and 12CH 2 D 2. We evaluated the optimized performance of a Panorama (Nu Instruments, UK) HR-IRMS system by repeated analysis of an intra-laboratory standard gas, finding that these rare isotopologues can be analyzed separately with high precision, repeatability, and reproducibility. Internal precision (a key parameter in instrument performance) reached 0.15‰ − 0.25‰ for Δ13CH 3 D and 0.70‰ − 0.85‰ for Δ12CH 2 D 2 values, ensuring the reliability of data. Comparison of results before and after purification demonstrated that purification procedures caused negligible isotopic fractionation of clumped isotopes. Isotopic-exchange experiments revealed source effects in the MS ion source, depending on the difference in bulk H isotopic composition between sample and reference gas, but independent of bulk C isotopic composition. To improve analytical accuracy for methane isotopologues, an absolute reference frame was developed through experiments involving a suite of mixed gases of different H isotopic composition equilibrated at 100 °C and a standard gas equilibrated at 2 °C–500 °C. Based on the reference frame, raw data were processed with a non-linearity correction and converted to real values with empirical transformation functions. The reference frame was applied to analyses of two methane standard gases and three natural gases from Tarim Basin, China. Measured Δ13CH 3 D and Δ12CH 2 D 2 values for two standard gases were consistent with published values. Clumped-isotope signatures of natural gases preserve information related to the formation temperature of methane. • Clumped-isotope analysis provides new constraints on the formation and evolution of methane. • Isotopic-exchange experiments demonstrated the presence of source scrambling in Panorama. • An absolute reference frame was established to calibrate source scrambling to achieve the accurate clumped-isotope value. • We measured CH 4 clumped-isotope of natural gases and proved that the absolute reference frame is accurate and feasible. [ABSTRACT FROM AUTHOR]

[Display omitted] • Conceptualisation of a solid oxide fuel cell-based cogeneration system. • Techno-economic assessments of the novel cogeneration system. • Influence of hydrogen blending with natural gas on system-level performance. • Application of Artificial Neural Network-based training on the simulated model data. A thorough investigation of the thermodynamics and economic performance of a cogeneration system based on solid oxide fuel cells that provides heat and power to homes has been carried out in this study. Additionally, different percentages of green hydrogen have been blended with natural gas to examine the techno-economic performance of the suggested cogeneration system. The energy and exergy efficiency of the system rises steadily as the hydrogen blending percentage rises from 0% to 20%, then slightly drops at 50% H 2 blending, and then rises steadily again until 100% H 2 supply. The system's minimal levelised cost of energy was calculated to be 4.64 £/kWh for 100% H 2. Artificial Neural Network (ANN) model was also used to further train a sizable quantity of data that was received from the simulation model. Heat, power, and levelised cost of energy estimates using the ANN model were found to be extremely accurate, with coefficients of determination of 0.99918, 0.99999, and 0.99888, respectively. [ABSTRACT FROM AUTHOR]

The introduction of hydrogen into the UK natural gas main has been reviewed in terms of how materials within the gas distribution network may be affected by contact with up to 80% Natural Gas (NG)/20 mol% hydrogen blend at up to 2 barg. A range of metallic, polymeric and elastomeric materials in the gas distribution network (GDN) were assessed via a combination of literature review and targeted practical test programmes. The work considered: • The effect of hydrogen on metallic materials identified in the network. • The effect of hydrogen on polymeric materials identified in the network. • The effect of hydrogen exposure on polyethylene pipeline joining and repair techniques (squeeze-off, and socket and saddle electrofusion joints) The experimental work involved soaking materials, under pressure conditions representative of the network, in 100% hydrogen, 20% hydrogen in methane, and 100% methane. For the metal samples, the test programme involved the assessment of hydrogen uptake on the tensile properties. For the polyethylene samples, the test programme looked at the assessment of possible hydrogen absorption/desorption and its effect on electrofusion jointing. The trials concluded that the majority of metallic materials showed no significant deterioration in mechanical (tensile) properties when stored in hydrogen environments compared to those stored in analogous methane or blended gas atmospheres up to 2 barg. Polymeric materials showed no deterioration to efficiency of squeeze-off or collar electrofusion in socket or shoulder orientations following soaking in hydrogen, methane or hydrogen blends. • Test samples were soaked in mixtures of hydrogen and methane gas at 2 barg. • No detrimental effect on the tensile properties of metallic materials was found. • PE80 pipework squeeze-off and electrofusion welding were not affected by hydrogen. [ABSTRACT FROM AUTHOR]

Increased penetration of renewable energy sources and decarbonisation of the UK's gas supply will require large-scale energy storage. Using hydrogen as an energy storage vector, we estimate that 150 TWh of seasonal storage is required to replace seasonal variations in natural gas production. Large-scale storage is best suited to porous rock reservoirs. We present a method to quantify the hydrogen storage capacity of gas fields and saline aquifers using data previously used to assess CO 2 storage potential. We calculate a P50 value of 6900 TWh of working gas capacity in gas fields and 2200 TWh in saline aquifers on the UK continental shelf, assuming a cushion gas requirement of 50%. Sensitivity analysis reveals low temperature storage sites with sealing rocks that can withstand high pressures are ideal sites. Gas fields in the Southern North Sea could utilise existing infrastructure and large offshore wind developments to develop large-scale offshore hydrogen production. Image 1 • UK requires 150 TWh of seasonal hydrogen storage capacity to decarbonise gas. • First quantification of hydrogen storage capacity in gas fields. • 6900 TWh hydrogen working gas capacity in UK offshore gas fields. • Low temperature/high pressure capacity storage sites are best. • Offshore gas fields and wind could develop offshore hydrogen production. [ABSTRACT FROM AUTHOR]

We report measurements of methane (CH4) mixing ratios and emission fluxes derived from sampling at a monitoring station at an exploratory shale gas extraction facility in Lancashire, England. Elevated ambient CH4 mixing ratios were recorded in January 2019 during a period of cold-venting associated with a nitrogen lift process at the facility. These processes are used to clear the well to stimulate flow of natural gas from the target shale. Estimates of CH4 flux during the emission event were made using three independent modeling approaches: Gaussian plume dispersion (following both a simple Gaussian plume inversion and the US EPA OTM 33-A method), and a Lagrangian stochastic transport model (WindTrax). The three methods yielded an estimated peak CH4 flux during January 2019 of approximately 70 g s−1. The total mass of CH4 emitted during the six-day venting period was calculated to be 2.9, 4.2 ± 1.4(1σ) and 7.1 ± 2.1(1σ) tonnes CH4 using the simple Gaussian plume model, WindTrax, and OTM-33A methods, respectively. Whilst the flux approaches all agreed within 1σ uncertainty, an estimate of 4.2 (± 1.4) tonnes CH4 represents the most confident assessment due to the explicit modeling of advection and meteorological stability permitted using the WindTrax model. This mass is consistent with fluxes calculated by the Environment Agency (in the range 2.7 to 6.8 tonnes CH4), using emission data provided by the shale site operator to the regulator. This study provides the first CH4 emission estimate for a nitrogen lift process and the first-reported flux monitoring of a UK shale gas site, and contributes to the evaluation of the environmental impacts of shale gas operations worldwide. This study also provides forward guidance on future monitoring applications and flux calculation in transient emission events. Implications: This manuscript discusses atmospheric measurements near to the UK's first hydraulic fracturing facility, which has very high UK public, media, and policy interest. The focus of this manuscript is on a single week of data in which a large venting event at the shale gas site saw emissions of ~4 tonnes of methane to atmosphere, in breach of environmental permits. These results are likely to beresults are likely to be reported by the media and may influence future policy decisions concerning the UK hydraulic fracturing industry. [ABSTRACT FROM AUTHOR]

In this study, we explore the lived experiences of communities at the frontier of shale gas extraction in the United Kingdom. We ask: How do local people experience shale gas development? What narratives and reasoning do individuals use to explain their support, opposition or ambivalence to unconventional hydrocarbon developments? How do they understand their lived experiences changing over time, and what sorts of coping strategies do they rely upon? To do so, we draw insights from semi-structured interviews with 31 individuals in Lancashire, England, living or working near the only active shale gas extraction operation in the UK until the government moratorium was announced in December of 2019. Through these data, we identify several themes of negative experiences, including "horrendous" participation, community "abuse," disillusionment and "disgust," and earthquakes with the potential to "ruin" lives. We also identify themes of positive experiences emphasizing togetherness and community "gelling", environmental "awareness," everyday energy security with gas as a "bridging fuel," and local employment with "high quality jobs." Finally, we identify themes of ambivalent and temporally dynamic experiences with shale gas that move from neutral to negative regarding vehicle traffic, and neutral to positive regarding disgust with protesting behaviour and the diversion of community resources. Our study offers context to high level policy concerns and also humanizes community and resident experiences close to fracking sites. [ABSTRACT FROM AUTHOR]

Despite the current moratorium, shale gas has been posited by the United Kingdom's government as an important indigenous source of natural gas, a result of heightened concerns over national energy security and dwindling conventional fossil fuel reserves. Although several petroleum development licenses were awarded in the Vale of Pickering area of North Yorkshire in 2015, little research exists at the nexus of social and natural sciences on shale gas developments, particularly on potential risks to communities and the environment in the UK. This study uses the concept of energy justice and an interdisciplinary spatial assessment of potential environmental risks arising from shale gas developments, to evaluate where injustices may emerge, using the Vale of Pickering as a case study. A novel methodology was used to model a possible scenario of shale gas developments, including the spatial dimensions of air and water pollution, seismicity and traffic flows, which were combined to generate an overall environmental risk assessment. This was analysed with a metric of socio-economic vulnerability, to highlight social groups which may be disproportionately at risk from fracking. Overall, modelled proximity-based risk under this scenario did not disproportionately increase in areas with higher populations of socio-economically vulnerable groups, however potential areas for other forms of energy injustices to emerge, such as benefit-sharing injustice were found. This study offers a holistic method for identifying and understanding the local socio-environmental justice dimensions of national energy projects, such as shale gas developments, considerations which can be integrated into future planning processes. [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]

The focus of this research is the potential of biomethane in Britain's gas grid. It examines its relative ability to address Britain's sustainability and energy security challenges from an economic perspective. Such research is important because UK is wedded to gas for heat production and power generation and is increasingly dependent on imported gas, in line with shrinking domestic production, and uncertain future trading relationships. Also, dependency on natural gas, threatens Britain achieving its legally-binding carbon budgets. The study included a thorough literature review, primary research to finally uncover the views of key UK market participants plus analytical modelling. The findings reveal that the market is cautiously optimistic, despite reservations regarding feedstock availability and the impending cessation of subsidy approvals. Investors are in greater need of long-term certainty, however, and the challenge of decarbonising heat and heavy-duty transport warrants this. Retail price premiums are polarised but, in line with wholesale costs, relatively high compared to electricity. The key recommendation is for the policymakers to follow precedents in renewable electricity and liquid biofuels, by mandating that energy suppliers, owners of heavy-duty road fleets and occupiers of new buildings purchase biomethane. In tandem, feedstock and grid-entry restrictions must be tackled creatively. • Dependency on natural gas threatens Britain achieving its carbon budgets. • Biomethane is a solution for sustainable and clean gas supply for the UK. • Cautiously optimistic market in the UK on the future of biomethane in the energy mix • Polarised retail price premiums for green gas relatively high compared to electricity • Recommendation: UK policymakers to follow renewable electricity precedents [ABSTRACT FROM AUTHOR]

Beneath the surface of the United Kingdom lies a sprawling natural gas infrastructure. Based on recent (2014/15) 'follow the thing' fieldwork conducted in the UK onshore gas industry, this paper explores the ways that dangers related to the subterranean circulation of natural gas come to be visualised, and how these visualisations make possible different security interventions. These practices are shown to be limited by the ground, which despite its enrolment as a security device conceals from view the shifting landscapes of risk that surround these gaseous movements. Drawing on Manuel DeLanda's concept of the possibility space, I provide a conceptual framework for attending to security's visualisation practices, describing how attempts are made to overcome the subsurface obfuscation of natural gas. I argue that, rather than being understood as a process of circulatory 'filtration' or 'maintenance', security must instead be regarded as a series of transformative practices of ecological (re)organisation that are predicated upon the visualisation of entities' spaces of possibility. In the process, I provide an account of how the three-dimensional geographies and materialities of gas circulations and their milieus are intimately tied up in their governance and politics. [ABSTRACT FROM AUTHOR]

Mandatory standard GB 17820-2018 Natural Gas has been published. The influence of this standard on the needs of sulfur contained reference gas is discussed. With the huge change in the natural gas quality control field, the traceability of worldwide H2S and SO2 reference gas is analyzed to carry out the demand to research and produce such reference gas. According to this mandatory standard, natural gas entering long distance pipeline should has no more than 6 mg/m3 H2S , the analysis methods on H2S in natural gas with such concentration is also listed in this standard. In order to get accurate analytic results, not only the analytic method is needed, but also the traceability is required. In other word, proper reference gas mixture is required to achieve good traceability and accuracy of the testing result in order to ensure the quality of the pipeline transmitted natural gas. [ABSTRACT FROM AUTHOR]

• A framework to calculate heat recovery from CO 2 refrigerated systems is presented. • Substantial heat is recovered but it does not match the instantaneous heating load. • Useful heat recovered in a UK supermarket case study ranges from 28.7% to 43.2%. • Heat recovery in normal conditions reduced natural gas use by 48% and costs by 6.2%. • The most efficient heat recovery strategy reduces energy use by 32%. This paper compares and quantifies the energy, environmental and economic benefits of various control strategies recovering heat from a CO 2 booster system in a supermarket for space heating with the purpose of understanding its potential for displacing natural gas fuelled boilers. A theoretical steady-state model that simulates the behaviour of the CO 2 system is developed and validated against field measurements obtained from an existing refrigeration system in a food-retail building located in the United Kingdom. Five heat recovery strategies are analysed by modifying the mass flow and pressure level in the condenser. The model shows that a reduction of 48% in natural-gas consumption is feasible by the installation of a de-superheater and without applying any advanced operating strategy. However, the CO 2 system can fully supply the entire space-heating requirements by adopting alternative control strategies, albeit by penalising the coefficient of performance (COP) of the compressor. Results show that the best energy strategy can reduce total consumption by 32%, while the best economic strategy can reduce costs by 6%. Findings from this work suggest that heat recovery systems can bring substantial benefits to improve the overall efficiency of energy-intensive buildings; nevertheless trade-offs need to be carefully considered and analysed on a site by site basis before embarking on such initiatives. [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]

This research provides new techno-economic insights into integrating flexible combined-cycle gas turbines with post-combustion carbon capture and storage (CCGT-CCS) for low-carbon power systems. This study developed a versatile unit-commitment optimisation model of CCGT-CCS. This research highlights the model's adaptability, accommodating diverse techno-economic configurations, feed gases (e.g., biomethane or fossil natural gas), carbon capture rates, and policy instruments. This generalisation empowers seamless application in various policy and market contexts, making the model a potent tool for researchers and policymakers. While the case study focuses on the UK, the findings are relevant for most low-carbon power systems with variable renewable supplies. Analysing the UK's net-zero scenarios from 2030 to 2050, the economic viability of flexible CCGT-CCS was highlighted. Intertemporal flexibility proves highly valuable with greater electricity price volatility, with a total ROI range of 81–246 %, surpassing the CCGT-CCS plant's ROI (7–64 %). A flexible solvent storage solution should be seen in the context of the overall system 'flexibility' requirements of a low-carbon power system. On a cost basis, solvent storage represents just a fraction of the capital costs of more "mainstream" energy storage technologies, such as lithium-ion batteries or hydro-pumped storage, while CCGT-CCS offers firm power. Overall, while seen as a rather technical solution, if abated fossil fuel generation is to be part of a future low-carbon power system, having this flexibility adds economic benefits not just to operators but also improves overall system security and complements high shares of variable renewables on the grid. [Display omitted] • Solvent storage in CCS can maximize profits from fluctuating low-carbon electricity markets. • Total return on investment from solvent storage greatly exceeds that of abated CCGT alone. • Solvent storage capital cost is a fraction of many "mainstream" energy storage technologies while providing firm power. • Flexible CCS with solvent storage boosts investor returns, system security, and aids renewable integration. [ABSTRACT FROM AUTHOR]

• Analyses the governance of the UK's rapid transition to natural gas. • Applies contemporary theories of steering. • Identifies how actors responded and coordinated action. • Examines modes of steering followed by key actors and institutions. • Offers insights into the steering and the management of sociotechnical transitions. The article studies the steering strategies pursued during a major sociotechnical transition in the then state-owned British gas industry. We focus on the ten-year (1967–1977) national project to convert 35 million appliances to run on natural gas instead of manufactured gas. The article : a. addresses the issue of steering in the multi-faceted, complex process of conversion and identifies the context of and challenges faced by the natural gas conversion programme in the 1960s and how actors responded and coordinated action; b. Identifies modes of steering followed by key actors and institutions of the period; c. Identifies essential precursors for this successful steering, including: the recognition of the challenges the industry faced in the pre-transition years; an openness to experimentation, R&D and organizational and technical change; and harmonious relations with government. We argue that the steering approach needs to combine an emphasis on planning and institutional and regulatory innovation with aspects of the mundane governance approach. Our analysis shows, with reference to the UK's low-carbon gas transition, that while rapid, planned transitions are achievable, they may require complex, demanding forms of steering and governance that may prove hard to achieve in today's socioeconomic and political conditions. [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]

We present a mass balance approach to estimate the seasonal and annual budgets of carbon dioxide (CO2) and methane (CH4) of the United Kingdom (excluding Scotland) and the Republic of Ireland from concentration measurements taken on a ferry along the east coast of the United Kingdom over a 3-year period (2015–2017). We estimate the annual emissions of CH4 to be 2.55±0.48 Tg, which is consistent with the combined 2.29 Tg reported to the United Nations Framework Convention on Climate Change by the individual countries. The net CO2 budget (i.e. including all anthropogenic and biogenic sources and sinks of CO2) is estimated at 881.0±125.8 Tg, with a net biogenic contribution of 458.7 Tg (taken as the difference between the estimated net emissions and the inventory value, which accounts for anthropogenic emissions only). The largest emissions for both gases were observed in a broad latitudinal band (52.5–54 ∘ N), which coincides with densely populated areas. The emissions of both gases were seasonal (maxima in winter and minima in summer), strongly correlated with natural gas usage and, to a lesser extent, also anti-correlated with mean air temperature. Methane emissions exhibited a statistically significant anti-correlation with air temperature at the seasonal timescale in the central region spanning 52.8–54.2 ∘ N, which hosts a relatively high density of waste treatment facilities. Methane emissions from landfills have been shown to sometimes increase with decreasing air temperature due to changes in the CH4 -oxidising potential of the topsoil, and we speculate that the waste sector contributes significantly to the CH4 budget of this central region. This study brings independent verification of the emission budgets estimated using alternative products (e.g. mass balance budgets by aircraft measurements, inverse modelling, inventorying) and offers an opportunity to investigate the seasonality of these emissions, which is usually not possible. [ABSTRACT FROM AUTHOR]

In 2017 the UK Health and Safety Executive commissioned a report (MH/17/27) on the suitability of the ISO 22899-1:2007 jet fire resistance test (JFRT) as a means of demonstrating performance of Passive Fire Protection (PFP) materials or systems to a range of jet fire scenarios. The aim was to address current industry concerns regarding the suitability of the test for characterising PFP materials response in' high heat flux' scenarios. The characterisation of a jet fire in terms of a single heat flux value is found to be an inadequate means of specifying the severity of the hazard. Instead, a detailed description of the nature of the release should be provided. To this end the flame characteristics are compared that influence PFP materials response for a range of release scenarios, including gas, flashing liquids, crude-oil, gas-liquid mixes (two-phase), hydrogen, cryogenic releases and releases into confined areas. The applicability of the JFRT to the various release scenarios is assessed through comparison of the conditions within the scenarios to those within the large-scale natural gas release scenario used during validation of the JFRT. [ABSTRACT FROM AUTHOR]

Natural gas pipelines are an important source of fugitive methane emissions in lifecycle greenhouse gas assessments but limited monitoring has taken place of UK pipelines to quantify fugitive emissions. This study investigated methane emissions from the UK high-pressure pipeline system (National Transmission System - NTS) for natural gas pipelines. Mobile surveys of CH 4 emissions were conducted across four areas in the UK, with routes bisecting high-pressure pipelines (with a maximum operating pressure of 85 bar) and separate control routes away from the pipelines. A manual survey of soil gas measurements was also conducted along one of the high-pressure pipelines using a tunable diode laser. For the pipeline routes, there were 26 peaks above 2.1 ppmv CH 4 at 0.23 peaks/km, compared with 12 peaks at 0.11 peaks/km on control routes. Three distinct thermogenic emissions were identified on the basis of the isotopic signal from these elevated concentrations with a peak rate of 0.03 peaks/km. A further three thermogenic emissions on pipeline routes were associated with pipeline infrastructure. Methane fluxes from control routes were statistically significantly lower than the fluxes measured on pipeline routes, with an overall pipeline flux of 627 (241–1123 interquartile range) tonnes CH 4 /km/yr. Soil gas CH 4 measurements indicated a total flux of 62.6 kt CH 4 /yr, which equates to 2.9% of total annual CH4 emissions in the UK. We recommend further monitoring of the UK natural gas pipeline network, with assessments of transmission and distribution stations, and distribution pipelines necessary. [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]

There is a projected shortcoming in the fourth carbon budget of 7.5%. This shortfall may be increased if the UK pursues a domestic shale gas industry to offset projected decreases in traditional gas supply. Here we estimate that, if the project domestic gas supply gap for power generation were to be met by UK shale gas with low fugitive emissions (0.08%), an additional 20.4 Mt CO 2 e 1 1 Megatonne carbon dioxide equivalent (Mt CO 2 e). would need to be accommodated during carbon budget periods 3–6. We find that a modest fugitive emissions rate (1%) for UK shale gas would increase global emissions compared to importing an equal quantity of Qatari liquefied natural gas. Additionally, we estimate that natural gas electricity generation would emit 420–466 Mt CO 2 e (460 central estimate) during the same time period within the traded EU emissions cap. We conclude that domestic shale gas production with even a modest 1% fugitive emissions rate would risk exceedance of UK carbon budgets. We also highlight that, under the current production-based greenhouse gas accounting system, the UK is incentivized to import natural gas rather than produce it domestically. [ABSTRACT FROM AUTHOR]

Britain’s gas system developed in the early 1800s. Over the past two centuries the system and its local, national and international networks have experienced much socio-technical innovation, governance changes and six key transitions. Since the Climate Change Act of 2008, it faces a seventh challenging transition as the UK moves uncertainly towards a low-carbon energy system, including decarbonising electricity, heat and transport. The paper explores: the origins of the system by Murdoch, Boulton and Watt; the early 19th century development of local gas networks; innovative responses to, inter alia, the challenge of incandescent electric light from the 1880s, including the expansion of the customer base and the development and active promotion of cooking and heat services – the growth, fragmentation and incoherence of the industry between the two World Wars; the post-war period that saw the industry nationalised in 1948, as the multi-fuel economy developed; the institutional, technical and social challenges associated with the conversion to North Sea natural gas in the 1960s; and innovation and change in response to the challenges that flowed from the privatisation of British Gas in 1987. The paper shows how examining past processes of innovation, transition and transformation through the lens of institutional ‘governance logics’ helps appreciate the challenges faced by system actors, technologies, institutions and regulators in the past and offers insights into the issues posed by the low-carbon transition. The paper begins by outlining some analytical concepts used in the analysis. We then examine the regime’s six past transitions. The paper concludes by considering what insights these past experiences suggest for a seventh transition towards a low-carbon economy, for the future governance of the UK gas system and its networks and particularly for natural gas. [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]

In this paper we raise a number of issues that are important for the UK to consider in the light of its decision to leave the European Union (EU). The first of these is the nature of the EU Single Market in Electricity and Gas and the UK's role within this. The second is the nature of UK energy policy in the light of Brexit, and the opportunities for changing this. And third, we consider some of the key issues to be addressed in a negotiating position with the EU. [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]

The article discusses the concerns related to the landowners in Great Britain due to the unrestrained growth of hydraulic fracturing. It mentions that hydraulic fracturing have impact on energy prices regardless of the supply of natural gas. It also mentions that problem related to the formation of lease agreements and the need to deliver the efficient resource allocation.

The article discusses the concerns related to the landowners in Great Britain due to the unrestrained growth of hydraulic fracturing. It mentions that hydraulic fracturing have impact on energy prices regardless of the supply of natural gas. It also mentions that problem related to the formation of lease agreements and the need to deliver the efficient resource allocation.

We investigate if and how gas price volatility can be explained on the basis of market fundamentals. We depart from the Kanamura (2009) supply and demand based volatility model. We generalize this model to account for a variety of demand and supply relationships. We investigate daily natural gas prices in the UK in the 21st century. We find that different supply curves exist in particular sub periods and we establish the presence of various leverage effects. We conclude that supply and demand based volatility models relying on different supply assumptions provide a sound theoretical and economic foundation for using GARCH models in the UK gas market. [ABSTRACT FROM AUTHOR]

Daily gas demand in the UK is variable. This is partly due to weather patterns and the changing nature of electricity markets, where intermittent wind energy levels lead to variations in the demand for gas needed to produce electricity. This uncertainty makes it difficult for traders in the market to analyse the market. As a result, there is an increasing need for models of the UK natural gas market that include stochastic demand. In this paper, a Rolling Optimisation Model (ROM) of the UK natural gas market is introduced. It takes as an input stochastically generated scenarios of demand. The outputs of ROM are the flows of gas, i.e., how the different sources of supply meet demand, as well as how gas flows in to and out of gas storage facilities. The outputs also include the daily System Average Price of gas in the UK. The model was found to fit reasonably well to historic data (from the UK National Grid) for the years starting on the 1st of April for both 2010 and 2011. These results allow ROM to be used to predict future flows and prices of gas and to investigate various stress-test scenarios in the UK natural gas market. [ABSTRACT FROM AUTHOR]

Highlights: [•] UK oil and gas production rate statistics similar to CO2 injection projects worldwide. [•] Median UK oil and gas production rate corresponds to around 0.35Mt/yr/well of CO2. [•] Brine production should typically lead to 20% reduction in number of required wells. [Copyright &y& Elsevier]

BP and Shell have reported record-breaking profits as the UK faces a natural gas crisis. The UK government is yet facing more calls for a windfall tax to be imposed on the industry. [ABSTRACT FROM AUTHOR]

The article focuses on unique licensing policy in Great Britain. It states that the country's government has proprietary rights to the petroleum reserves and compelled to turn to private companies who hold most of the financial and technical means needed for the exploration and exploitation of petroleum resources. It further discusses the Petroleum (Production) Act 1934 and petroleum production licenses.