Chris Jones

@article{a671d80d2f284e7a9213d8759446fc0a,

title = {What does the Paris Climate Change Agreement mean for local policy? Downscaling the remaining global carbon budget to sub-national areas.},

author = {Jaise Kuriakose and Christopher Jones and Kevin Anderson and Carly McLachlan and John Broderick},

doi = {10.1016/j.rset.2022.100030},

issn = {2667-095X},

year  = {2022},

date = {2022-08-01},

journal = {Renewable and Sustainable Energy Transition},

publisher = {Elsevier BV},

abstract = {Following high profile United Nations climate summits in Glasgow and Paris, sub-national regions and cities are increasingly seeking to set climate targets and policies in line with the Paris Agreement’s goals. Downscaled carbon budgets are a useful framework for setting local mitigation targets related to a specific global temperature change. However, doing so presents a range of methodological issues, including: choices on the appropriate goals to set, the scope of emissions and sectors, the allocation approaches to apply, whether offset credits and/or carbon dioxide removals are acceptable and, if so, to what extent. This paper details a novel and transparent methodology for downscaling a Paris-aligned global carbon budget to sub-national areas, focusing on emissions from energy (power, heat, cooling, surface transport and industry). The effects of different global carbon budgets, various net zero targets and allocation methods on the size of sub-national budgets and associated mitigation rates are explored. The resulting budgets and annual emission reduction rates vary significantly, reflecting the implications of both high-level methodological choices and local factors, including economic activity, energy-system structure and population. Recent historical emissions (grandfathering) are found to be more appropriate for allocating national carbon budgets to sub-national areas than capability or egalitarian allocations. In the UK case study presented, adopting a grandfathering approach, the annual mitigation rates range from 7% to 16% between different sub-national areas. The analysis concludes that establishing agreed sub-national allocation approaches and boundaries are key to developing coherent national strategies consistent with the Paris Agreement’s temperature and equity commitments.},

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}

@article{3f45699dc91c4b0292b24e9cd195b618,

title = {Responding to the climate emergency: how are UK universities establishing sustainable workplace routines for flying and food?},

author = {Claire Hoolohan and Carly McLachlan and Christopher Jones and Alice Larkin and Christina Birch and Sarah Mander and John Broderick},

issn = {1469-3062},

year  = {2021},

date = {2021-01-21},

journal = {Climate Policy},

publisher = {Earthscan},

abstract = {Scope 3 emissions from the UK higher education sector are globally significant, and long-distance air travel and catering are particularly emissions-intensive aspects of workplace routine. They each present complex problems, as transition to low-carbon alternatives requires the reconfiguration of professional practices. This paper examines the sustainability policies of 66 UK universities to establish the extent to which planning and action in these areas are commensurate with climate emergency declarations. The findings indicate that universities recognise their role in creating demand for long-distance travel and sustaining high-carbon diets. However, few have specific emissions reduction targets or action plans that would rapidly and substantially reduce emissions in these areas. Discussion focuses on two core points; first, how greater cohesion in reporting and target-setting can be achieved across the sector to raise the ambition of targets and intervention; and second to identify opportunities for institutions to disrupt and reshape professional practices to reduce emissions in these areas.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{3f45699dc91c4b0292b24e9cd195b618b,

title = {Responding to the climate emergency: how are UK universities establishing sustainable workplace routines for flying and food?},

author = {Claire Hoolohan and Carly McLachlan and Christopher Jones and Alice Larkin and Christina Birch and Sarah Mander and John Broderick},

issn = {1469-3062},

year  = {2021},

date = {2021-01-21},

journal = {Climate Policy},

publisher = {Earthscan},

abstract = {Scope 3 emissions from the UK higher education sector are globally significant, and long-distance air travel and catering are particularly emissions-intensive aspects of workplace routine. They each present complex problems, as transition to low-carbon alternatives requires the reconfiguration of professional practices. This paper examines the sustainability policies of 66 UK universities to establish the extent to which planning and action in these areas are commensurate with climate emergency declarations. The findings indicate that universities recognise their role in creating demand for long-distance travel and sustaining high-carbon diets. However, few have specific emissions reduction targets or action plans that would rapidly and substantially reduce emissions in these areas. Discussion focuses on two core points; first, how greater cohesion in reporting and target-setting can be achieved across the sector to raise the ambition of targets and intervention; and second to identify opportunities for institutions to disrupt and reshape professional practices to reduce emissions in these areas.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{5c5bd3e0d51444c88db392c86909a4ec,

title = {Assessing the Climate Change Mitigation Potential of Stationary Energy Storage for Electricity Grid Services},

author = {Christopher Jones and Paul J Gilbert and Laurence Stamford},

doi = {10.1021/acs.est.9b06231},

issn = {0013-936X},

year  = {2019},

date = {2019-01-01},

journal = {Environmental Science & Technology},

publisher = {American Chemical Society},

abstract = {This paper presents a life cycle assessment for three stationary energy storage systems (ESS); lithium iron phosphate (LFP) battery, vanadium redox flow battery (VRFB) and liquid air energy storage (LAES). The global warming potential (GWP) is assessed in relation to uncertainties in usage of the storage, use-phase energy input, cell replacement and round trip efficiency parameters. Relative climate change mitigation potential in comparison with equivalent diesel-electric and natural gas generation is discussed, as is the effect of recycling at end of life. With variations in input electricity source, recycling and efficiency, the life cycle global warming potential for LFP ranges from 185 kg CO2eq/MWh to 440 kg CO2eq/MWh; for VRFB from 121 kg CO2eq/MWh to 443 kg CO2eq/MWh; and for LAES from 48 kg CO-2eq/MWh to 203 kg CO2eq/MWh. In all cases there are climate change mitigation benefits compared to fossil fuel alternatives. Use of renewable energy for charging and operation, ease of component recycling/reuse and reduced parts replacement is shown to reduce GWP. The climate change mitigation potential of ESS for electricity grid operation is further enhanced by increasing use of the storage assets. Recycling of ESS is shown to reduce terrestrial acidification, freshwater eutrophication and particulate matter impacts. Reduced ozone depletion potential for VRFB and LFP can be achieved by reducing nafion and PVDF components respectively.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{5c5bd3e0d51444c88db392c86909a4ecb,

title = {Assessing the Climate Change Mitigation Potential of Stationary Energy Storage for Electricity Grid Services},

author = {Christopher Jones and Paul J Gilbert and Laurence Stamford},

doi = {10.1021/acs.est.9b06231},

issn = {0013-936X},

year  = {2019},

date = {2019-01-01},

journal = {Environmental Science & Technology},

publisher = {American Chemical Society},

abstract = {This paper presents a life cycle assessment for three stationary energy storage systems (ESS); lithium iron phosphate (LFP) battery, vanadium redox flow battery (VRFB) and liquid air energy storage (LAES). The global warming potential (GWP) is assessed in relation to uncertainties in usage of the storage, use-phase energy input, cell replacement and round trip efficiency parameters. Relative climate change mitigation potential in comparison with equivalent diesel-electric and natural gas generation is discussed, as is the effect of recycling at end of life. With variations in input electricity source, recycling and efficiency, the life cycle global warming potential for LFP ranges from 185 kg CO2eq/MWh to 440 kg CO2eq/MWh; for VRFB from 121 kg CO2eq/MWh to 443 kg CO2eq/MWh; and for LAES from 48 kg CO-2eq/MWh to 203 kg CO2eq/MWh. In all cases there are climate change mitigation benefits compared to fossil fuel alternatives. Use of renewable energy for charging and operation, ease of component recycling/reuse and reduced parts replacement is shown to reduce GWP. The climate change mitigation potential of ESS for electricity grid operation is further enhanced by increasing use of the storage assets. Recycling of ESS is shown to reduce terrestrial acidification, freshwater eutrophication and particulate matter impacts. Reduced ozone depletion potential for VRFB and LFP can be achieved by reducing nafion and PVDF components respectively.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{ad22f595bcc6472f8ed499ed45892206,

title = {A multi-disciplinary analysis of UK grid mix scenarios with large-scale PV deployment},

author = {Marco Raugei and Enrica Leccisi and Brian Azzopardi and Christopher Jones and Paul Gilbert and Lingxi Zhang and Yutian Zhou and Sarah Mander and Pierluigi Mancarella},

doi = {10.1016/j.enpol.2017.11.062},

issn = {0301-4215},

year  = {2018},

date = {2018-03-01},

journal = {Energy Policy},

volume = {114},

pages = {51–62},

publisher = {Elsevier BV},

abstract = {The increasing contribution of renewable energies to electricity grids in order to address impending environmental challenges implies a reduction in non-renewable resource use and an alignment with a global transition toward a low-carbon electric sector. In this paper, four future UK grid mix scenarios with increased photovoltaic (PV) installed capacity are assessed and compared to a benchmark “Low PV” scenario, from 2016 to 2035. The complexity of the issue requires a multi-disciplinary approach to evaluate the availability of net energy, environmental aspects and technical performance. Hence, the comparison between scenarios includes short-term and long-term energy metrics as well as greenhouse gas (GHG) and technical metrics. Also, the paper considers the viewpoints offered by both an “integrative” and a “dynamic” approach to net energy analysis. Results for all five analysed scenarios indicate that increased PV deployment will not be detrimental to the UK grid performance from the points of view of a wide range of system-level technical (% renewable energy curtailment to ensure grid stability), energy (energy return on investment and non-renewable cumulative energy demand) and environmental (greenhouse gas emissions) metrics.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{2043,

title = {Determining the consequential life cycle greenhouse gas emissions of increased rooftop photovoltaic deployment},

author = {C Jones and P Gilbert},

url = {https://www.sciencedirect.com/science/article/pii/S0959652618304530},

doi = {10.1016/j.jclepro.2018.02.140},

year  = {2018},

date = {2018-01-01},

journal = {Journal of Cleaner Production},

volume = {184},

pages = {211-219},

chapter = {211},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{2051,

title = {A multi-disciplinary analysis of UK grid mix scenarios with large-scale PV deployment},

author = {M Raugei and E Leccisi and B Azzopardi and C Jones and P Gilbert and L Zhang and Y Zhou and S Mander and PL Mancarella},

url = {https://www.sciencedirect.com/science/article/pii/S030142151730808X},

doi = {10.1016/j.enpol.2017.11.062},

year  = {2018},

date = {2018-01-01},

journal = {Energy Policy},

volume = {114},

pages = {51-62},

chapter = {51},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{a7f2dc27cf9749369ec8d14dea36886e,

title = {Determining the Consequential Life Cycle Greenhouse Gas Emissions of Increased Rooftop Photovoltaic Deployment},

author = {Christopher Jones and Paul Gilbert},

doi = {10.1016/j.jclepro.2018.02.140},

issn = {0959-6526},

year  = {2018},

date = {2018-01-01},

journal = {Journal of Cleaner Production},

publisher = {Elsevier BV},

abstract = {Increased power flows on electricity distribution networks, caused by growing photovoltaics (PV) uptake, can result in the implementation of solutions to maintain network function. This study takes a consequential life cycle assessment (LCA) approach to assess the greenhouse gas emissions (GHG) of aggregated PV electricity generation at the distribution network level. The study also considers how future changes in the manufacturing phase of Chinese and Malaysian PV modules, over the period of increasing PV deployment, may affect their GHG emissions. The study finds rooftop PV life cycle values of 21 to 107 gCO2e/kWh, for various UK PV output yield estimates and module types (Chinese made mono-crystalline (c-Si) and multi-crystalline silicon (Mc-Si), and Malaysian made cadmium telluride (CdTe)) installed in 2015. Prospective assessment of proposed future material efficiency and grid decarbonisation reduces the range to 21 to 87 gCO2e/kWh for modules installed after 2030. Consequential life cycle emissions from network solutions to accommodate growing PV generation shows increased GHG emissions attributable to PV by up to 13% (c-Si and Mc-Si) and 17% (CdTe) where 100% of network users connected install rooftop PV. There is however only a negligible increase in emissions if <60% of network users install PV. Voltage control solutions to network constraints caused by PV are found to minimise the contribution of network solutions to aggregated PV life cycle emissions to 2% (c-Si and Mc-Si) and 6% (CdTe) at 100% user uptake. The study concludes that even with network solutions for high penetrations of rooftop PV, there is a minimal (<6% with voltage control) increase in PV GHG emissions when assessed at a network level. Future changes in PV manufacturing could offset the effect of network solutions.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{3950098a0dac4943a18f3b22326c04f2,

title = {Challenges to the use of BECCS as a keystone technology in pursuit of 1.5⁰C},

author = {Clair Gough and Samira Garcia Freites and Christopher Jones and Sarah Mander and Brendan Moore and Cristina Pereira and Mirjam Roeder and Naomi Vaughan and Andrew Welfle},

doi = {10.1017/sus.2018.3},

year  = {2018},

date = {2018-01-01},

journal = {Global Sustainability},

volume = {1},

publisher = {Cambridge University Press},

abstract = {The UNFCCC Paris Agreement sets a goal of limiting the global temperature increase to “well below 2°C” and to pursue “efforts to limit the temperature increase to 1.5°C”. Most emission pathways that are compatible with these goals are heavily reliant on negative emissions technologies (NETs), especially biomass energy with carbon capture and storage (BECCS), at a global scale to remove CO2 from the atmosphere. The use of negative emissions in climate mitigation introduces a complex variety of technologies whose desirability, effectiveness and viability remain highly uncertain. This paper explores six key policy and governance challenges associated with BECCS, suggesting ways in which research could address some of these challenges: (1) How does BECCS fit with carbon budgets? (2) How negative is BECCS? (3) Can BECCS be delivered at sufficient scale? (4) Can sufficient biomass be provided sustainably? (5) How does BECCS fit into the policy context? (6) How does BECCS fit with climate agreements? Consideration of these challenges highlights the importance of a whole systems approach to assessing the use of BECCS and its potential as a keystone technology to deliver negative emissions.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{a7f2dc27cf9749369ec8d14dea36886eb,

title = {Determining the Consequential Life Cycle Greenhouse Gas Emissions of Increased Rooftop Photovoltaic Deployment},

author = {Christopher Jones and Paul Gilbert},

doi = {10.1016/j.jclepro.2018.02.140},

issn = {0959-6526},

year  = {2018},

date = {2018-01-01},

journal = {Journal of Cleaner Production},

publisher = {Elsevier BV},

abstract = {Increased power flows on electricity distribution networks, caused by growing photovoltaics (PV) uptake, can result in the implementation of solutions to maintain network function. This study takes a consequential life cycle assessment (LCA) approach to assess the greenhouse gas emissions (GHG) of aggregated PV electricity generation at the distribution network level. The study also considers how future changes in the manufacturing phase of Chinese and Malaysian PV modules, over the period of increasing PV deployment, may affect their GHG emissions. The study finds rooftop PV life cycle values of 21 to 107 gCO2e/kWh, for various UK PV output yield estimates and module types (Chinese made mono-crystalline (c-Si) and multi-crystalline silicon (Mc-Si), and Malaysian made cadmium telluride (CdTe)) installed in 2015. Prospective assessment of proposed future material efficiency and grid decarbonisation reduces the range to 21 to 87 gCO2e/kWh for modules installed after 2030. Consequential life cycle emissions from network solutions to accommodate growing PV generation shows increased GHG emissions attributable to PV by up to 13% (c-Si and Mc-Si) and 17% (CdTe) where 100% of network users connected install rooftop PV. There is however only a negligible increase in emissions if <60% of network users install PV. Voltage control solutions to network constraints caused by PV are found to minimise the contribution of network solutions to aggregated PV life cycle emissions to 2% (c-Si and Mc-Si) and 6% (CdTe) at 100% user uptake. The study concludes that even with network solutions for high penetrations of rooftop PV, there is a minimal (<6% with voltage control) increase in PV GHG emissions when assessed at a network level. Future changes in PV manufacturing could offset the effect of network solutions.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{3950098a0dac4943a18f3b22326c04f2b,

title = {Challenges to the use of BECCS as a keystone technology in pursuit of 1.5⁰C},

author = {Clair Gough and Samira Garcia Freites and Christopher Jones and Sarah Mander and Brendan Moore and Cristina Pereira and Mirjam Roeder and Naomi Vaughan and Andrew Welfle},

doi = {10.1017/sus.2018.3},

year  = {2018},

date = {2018-01-01},

journal = {Global Sustainability},

volume = {1},

publisher = {Cambridge University Press},

abstract = {The UNFCCC Paris Agreement sets a goal of limiting the global temperature increase to “well below 2°C” and to pursue “efforts to limit the temperature increase to 1.5°C”. Most emission pathways that are compatible with these goals are heavily reliant on negative emissions technologies (NETs), especially biomass energy with carbon capture and storage (BECCS), at a global scale to remove CO2 from the atmosphere. The use of negative emissions in climate mitigation introduces a complex variety of technologies whose desirability, effectiveness and viability remain highly uncertain. This paper explores six key policy and governance challenges associated with BECCS, suggesting ways in which research could address some of these challenges: (1) How does BECCS fit with carbon budgets? (2) How negative is BECCS? (3) Can BECCS be delivered at sufficient scale? (4) Can sufficient biomass be provided sustainably? (5) How does BECCS fit into the policy context? (6) How does BECCS fit with climate agreements? Consideration of these challenges highlights the importance of a whole systems approach to assessing the use of BECCS and its potential as a keystone technology to deliver negative emissions.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{a845540740964f6a86897384d08473bc,

title = {Battery storage for post-incentive PV uptake?:: A financial and life cycle carbon assessment of a non-domestic building},

author = {Christopher Jones and Vladimir Peshev and Paul Gilbert and Sarah Mander},

doi = {10.1016/j.jclepro.2017.08.191},

issn = {0959-6526},

year  = {2017},

date = {2017-11-20},

journal = {Journal of Cleaner Production},

volume = {167},

pages = {447–458},

publisher = {Elsevier BV},

abstract = {Therapid growth of photovoltaic (PV) installations in recent years has largely beendriven by government incentive schemes that make PV an attractive option forbuilding owners seeking to reduce their greenhouse gas emissions and energycosts. As government incentives are reduced or withdrawn the incorporation ofbattery storage, to lower building electricity grid imports through increasedon-site PV self-consumption, is an option to sustain rooftop PV uptake. Thisstudy combines a life cycle assessment approach and discounted cash flowanalysis to assess the CO2 and financial impact of adding battery storageto a PV assemblage in the context of future incentive withdrawal, electricitysystem decarbonisation and changing technology costs. An example non-domesticbuilding in the UK with a 20kW mono-crystalline silicon PV and 20kWhlithium-ion battery is modelled. With electricity grid decarbonisation in linewith the Paris Climate Change Agreement, the PV and battery system reduces thebuilding’s CO2 emissions by 15% (18tCO2) compared withthe grid-only reference over a 30year lifetime. The analysis also highlightsthat battery storage operated only to increase self-consumption of gridconnected rooftop PV does not necessarily increase C02 savings ofthe building with wider grid decarbonisation. For the 7%/annum technology costreduction rate examined, adding battery storage to a building’s PVconfiguration negatively affects financial performance for systems installed in2020. PV systems without batteries in the UK are however found to be viable in2020 without government incentives. The study concludes that battery costs haveto fall considerably, or additional revenue from providing electricity systemservices is needed to make batteries financially attractive in lower insolationareas like the UK. Policy to reduce electricity system CO2 through buildingintegrated battery uptake requires better understanding of the net system CO2impact in line with other changes in electricity generation and demand.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{a845540740964f6a86897384d08473bcb,

title = {Battery storage for post-incentive PV uptake?:: A financial and life cycle carbon assessment of a non-domestic building},

author = {Christopher Jones and Vladimir Peshev and Paul Gilbert and Sarah Mander},

doi = {10.1016/j.jclepro.2017.08.191},

issn = {0959-6526},

year  = {2017},

date = {2017-11-20},

journal = {Journal of Cleaner Production},

volume = {167},

pages = {447–458},

publisher = {Elsevier BV},

abstract = {Therapid growth of photovoltaic (PV) installations in recent years has largely beendriven by government incentive schemes that make PV an attractive option forbuilding owners seeking to reduce their greenhouse gas emissions and energycosts. As government incentives are reduced or withdrawn the incorporation ofbattery storage, to lower building electricity grid imports through increasedon-site PV self-consumption, is an option to sustain rooftop PV uptake. Thisstudy combines a life cycle assessment approach and discounted cash flowanalysis to assess the CO2 and financial impact of adding battery storageto a PV assemblage in the context of future incentive withdrawal, electricitysystem decarbonisation and changing technology costs. An example non-domesticbuilding in the UK with a 20kW mono-crystalline silicon PV and 20kWhlithium-ion battery is modelled. With electricity grid decarbonisation in linewith the Paris Climate Change Agreement, the PV and battery system reduces thebuilding’s CO2 emissions by 15% (18tCO2) compared withthe grid-only reference over a 30year lifetime. The analysis also highlightsthat battery storage operated only to increase self-consumption of gridconnected rooftop PV does not necessarily increase C02 savings ofthe building with wider grid decarbonisation. For the 7%/annum technology costreduction rate examined, adding battery storage to a building’s PVconfiguration negatively affects financial performance for systems installed in2020. PV systems without batteries in the UK are however found to be viable in2020 without government incentives. The study concludes that battery costs haveto fall considerably, or additional revenue from providing electricity systemservices is needed to make batteries financially attractive in lower insolationareas like the UK. Policy to reduce electricity system CO2 through buildingintegrated battery uptake requires better understanding of the net system CO2impact in line with other changes in electricity generation and demand.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{1674,

title = {An approach to prospective consequential life cycle assessment and net energy analysis of distributed electricity generation},

author = {Christopher Jones and Paul Gilbert and Marco Raugei and S Mander and Enrica Leccisi},

doi = {DOI: 10.1016/j.enpol.2016.08.030},

year  = {2017},

date = {2017-01-01},

abstract = {<p>Increasing distributed renewable electricity generation is one of a number of technology pathways available to policy makers to meet environmental and other sustainability goals. Determining the efficacy of such a pathway for a national electricity system implies evaluating whole system change in future scenarios. Life cycle assessment (LCA) and net energy analysis (NEA) are two methodologies suitable for prospective and consequential analysis of energy performance and associated impacts. This paper discusses the benefits and limitations of prospective and consequential LCA and NEA analysis of distributed generation. It concludes that a combined LCA and NEA approach is a valuable tool for decision makers if a number of recommendations are addressed. Static and dynamic temporal allocation are both needed for a fair comparison of distributed renewables with thermal power stations to account for their different impact profiles over time. The trade-offs between comprehensiveness and uncertainty in consequential analysis should be acknowledged, with system boundary expansion and system simulation models limited to those clearly justified by the research goal. The results of this approach are explorative, rather than for accounting purposes; this interpretive remit, and the assumptions in scenarios and system models on which results are contingent, must be clear to end users. (C) 2016 The Authors. Published by Elsevier Ltd.</p>},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{01ade7f10f35425a9ba98a630bd2608f,

title = {An Approach to Prospective Consequential Life Cycle Assessment and Net Energy Analysis of Distributed Electricity Generation},

author = {Christopher Jones and Paul Gilbert and Marco Raugei and Sarah Mander and Enrica Leccisi},

doi = {10.1016/j.enpol.2016.08.030},

issn = {0301-4215},

year  = {2017},

date = {2017-01-01},

journal = {Energy Policy},

volume = {100},

publisher = {Elsevier BV},

abstract = {Increasing distributed renewable electricity generation is one of a number of technology pathways available to policy makers to meet environmental and other sustainability goals. Determining the efficacy of such a pathway for a national electricity system implies evaluating whole system change in future scenarios. Life cycle assessment (LCA) and net energy analysis (NEA) are two methodologies suitable for prospective and consequential analysis of energy performance and associated impacts. This paper discusses the benefits and limitations of prospective and consequential LCA and NEA analysis of distributed generation. It concludes that a combined LCA and NEA approach is a valuable tool for decision makers if a number of recommendations are addressed. Static and dynamic temporal allocation are both needed for a fair comparison of distributed renewables with thermal power stations to account for their different impact profiles over time. The trade-offs between comprehensiveness and uncertainty in consequential analysis should be acknowledged, with system boundary expansion and system simulation models limited to those clearly justified by the research goal. The results of this approach are explorative, rather than for accounting purposes; this interpretive remit, and the assumptions in scenarios and system models on which results are contingent, must be clear to end users.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{01ade7f10f35425a9ba98a630bd2608fb,

title = {An Approach to Prospective Consequential Life Cycle Assessment and Net Energy Analysis of Distributed Electricity Generation},

author = {Christopher Jones and Paul Gilbert and Marco Raugei and Sarah Mander and Enrica Leccisi},

doi = {10.1016/j.enpol.2016.08.030},

issn = {0301-4215},

year  = {2017},

date = {2017-01-01},

journal = {Energy Policy},

volume = {100},

publisher = {Elsevier BV},

abstract = {Increasing distributed renewable electricity generation is one of a number of technology pathways available to policy makers to meet environmental and other sustainability goals. Determining the efficacy of such a pathway for a national electricity system implies evaluating whole system change in future scenarios. Life cycle assessment (LCA) and net energy analysis (NEA) are two methodologies suitable for prospective and consequential analysis of energy performance and associated impacts. This paper discusses the benefits and limitations of prospective and consequential LCA and NEA analysis of distributed generation. It concludes that a combined LCA and NEA approach is a valuable tool for decision makers if a number of recommendations are addressed. Static and dynamic temporal allocation are both needed for a fair comparison of distributed renewables with thermal power stations to account for their different impact profiles over time. The trade-offs between comprehensiveness and uncertainty in consequential analysis should be acknowledged, with system boundary expansion and system simulation models limited to those clearly justified by the research goal. The results of this approach are explorative, rather than for accounting purposes; this interpretive remit, and the assumptions in scenarios and system models on which results are contingent, must be clear to end users.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{317e82a51db348b1a75f510cc7b895c6,

title = {Poorest countries experience earlier anthropogenic emergence of daily temperature extremes},

author = {Luke Harrington and D Frame and Erich Fischer and Ed Hawkins and Manoj Joshi and Chris Jones},

doi = {10.1088/1748-9326/11/5/055007},

issn = {1748-9326},

year  = {2016},

date = {2016-05-01},

journal = {Environmental Research Letters},

volume = {11},

number = {5},

publisher = {IOP Publishing Ltd},

abstract = {Understanding how the emergence of the anthropogenic warming signal from the noise of internal variability translates to changes in extreme event occurrence is of crucial societal importance. By utilising simulations of cumulative carbon dioxide (CO2) emissions and temperature changes from eleven earth system models, we demonstrate that the inherently lower internal variability found at tropical latitudes results in large increases in the frequency of extreme daily temperatures (exceedances of the 99.9th percentile derived from pre-industrial climate simulations) occurring much earlier than for mid-to-high latitude regions. Most of the world’s poorest people live at low latitudes, when considering 2010 GDP-PPP per capita; conversely the wealthiest population quintile disproportionately inhabit more variable mid-latitude climates. Consequently, the fraction of the global population in the lowest socio-economic quintile is exposed to substantially more frequent daily temperature extremes after much lower increases in both mean global warming and cumulative CO2 emissions.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{37a199e41cc64eedb3f0aae3e4f0a825,

title = {Discounting the future of climate change in Russia},

author = {Maria Sharmina and Christopher Jones},

year  = {2015},

date = {2015-01-22},

journal = {OpenDemocracy.net},

publisher = {openDemocracy Limited},

abstract = {The future is not what it used to be. Giant methane ‘holes’, intense snowmelt floods, and more extreme weather events – these are just some of the future climate change impacts Roshydromet expects to see in Russia. At the same time, we keep hearing that climate change might actually be good for Russia. There is a view that it will benefit the country through a shorter winter season, better temperatures for growing food, and more accessible oil and gas in the Far North. There is a lot of uncertainty about what exactly will happen as the greenhouse gases from human activity push up the average global temperature. What we do know is that the risks are massive and need to be taken seriously. And it is misleading to think that the short-term benefits will last; Russians need to be aware of the longer-term damage that may come from not addressing this issue. Like it or not, global warming will change the country, and ignoring it only stores up problems for later. Russian history gives the current government plenty of lessons on the dangers of ignoring economic, social, and physical realities. The collapse of the Tsarist and Soviet regimes, which were unable to adapt to changing social and economic pressures from inside Russia and from globalisation, demonstrates this. Historical analogies only go so far, but we ignore their lessons at our peril. For this reason, climate change should be a high-priority in both Russia’s domestic and foreign affairs.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{37a199e41cc64eedb3f0aae3e4f0a825b,

title = {Discounting the future of climate change in Russia},

author = {Maria Sharmina and Christopher Jones},

year  = {2015},

date = {2015-01-22},

journal = {OpenDemocracy.net},

publisher = {openDemocracy Limited},

abstract = {The future is not what it used to be. Giant methane ‘holes’, intense snowmelt floods, and more extreme weather events – these are just some of the future climate change impacts Roshydromet expects to see in Russia. At the same time, we keep hearing that climate change might actually be good for Russia. There is a view that it will benefit the country through a shorter winter season, better temperatures for growing food, and more accessible oil and gas in the Far North. There is a lot of uncertainty about what exactly will happen as the greenhouse gases from human activity push up the average global temperature. What we do know is that the risks are massive and need to be taken seriously. And it is misleading to think that the short-term benefits will last; Russians need to be aware of the longer-term damage that may come from not addressing this issue. Like it or not, global warming will change the country, and ignoring it only stores up problems for later. Russian history gives the current government plenty of lessons on the dangers of ignoring economic, social, and physical realities. The collapse of the Tsarist and Soviet regimes, which were unable to adapt to changing social and economic pressures from inside Russia and from globalisation, demonstrates this. Historical analogies only go so far, but we ignore their lessons at our peril. For this reason, climate change should be a high-priority in both Russia’s domestic and foreign affairs.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{da1ae80be6cc4ac892a21ed989852440,

title = {Don't lock me in: Public opinion on the prospective use of waste process heat for district heating},

author = {Christopher Jones and P Upham},

issn = {0306-2619},

year  = {2012},

date = {2012-01-01},

journal = {Applied Energy},

volume = {89},

number = {0},

pages = {21–29},

publisher = {Elsevier BV},

abstract = {While the available resource in terms of waste process heat in the UK is substantial, there are a wide variety of issues to consider and barriers to overcome in order to realise its potential. This paper discusses one particular factor, namely public opinion. We describe the results of two focus groups with a potential domestic client group, namely elderly people, and the postal questionnaire responses of 323 individuals living in the proximity of a large potential heat source, namely the Corus steel-works in Port Talbot, Wales. While those questioned were broadly supportive of the idea of district heating, particularly if this would involve reductions in domestic heating costs, both the qualitative and quantitative work revealed significant concern about contractual lock-in. In contrast, the stability of long-term demand is highly valued by those responsible for the supply-side. We also observe some gender differences in first reactions to district heating and the role of environmental commitment. We conclude that while the results imply that an appeal to the environmental performance of district heating with waste heat may facilitate acceptance, trust-building and price inducements will also be required to overcome end-user concerns.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{da1ae80be6cc4ac892a21ed989852440b,

title = {Don't lock me in: Public opinion on the prospective use of waste process heat for district heating},

author = {Christopher Jones and P Upham},

issn = {0306-2619},

year  = {2012},

date = {2012-01-01},

journal = {Applied Energy},

volume = {89},

number = {0},

pages = {21–29},

publisher = {Elsevier BV},

abstract = {While the available resource in terms of waste process heat in the UK is substantial, there are a wide variety of issues to consider and barriers to overcome in order to realise its potential. This paper discusses one particular factor, namely public opinion. We describe the results of two focus groups with a potential domestic client group, namely elderly people, and the postal questionnaire responses of 323 individuals living in the proximity of a large potential heat source, namely the Corus steel-works in Port Talbot, Wales. While those questioned were broadly supportive of the idea of district heating, particularly if this would involve reductions in domestic heating costs, both the qualitative and quantitative work revealed significant concern about contractual lock-in. In contrast, the stability of long-term demand is highly valued by those responsible for the supply-side. We also observe some gender differences in first reactions to district heating and the role of environmental commitment. We conclude that while the results imply that an appeal to the environmental performance of district heating with waste heat may facilitate acceptance, trust-building and price inducements will also be required to overcome end-user concerns.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{ad22f595bcc6472f8ed499ed45892206b,

title = {A multi-disciplinary analysis of UK grid mix scenarios with large-scale PV deployment},

author = {Marco Raugei and Enrica Leccisi and Brian Azzopardi and Christopher Jones and Paul Gilbert and Lingxi Zhang and Yutian Zhou and Sarah Mander and Pierluigi Mancarella},

doi = {10.1016/j.enpol.2017.11.062},

issn = {0301-4215},

journal = {Energy Policy},

volume = {114},

pages = {51–62},

publisher = {Elsevier BV},

abstract = {The increasing contribution of renewable energies to electricity grids in order to address impending environmental challenges implies a reduction in non-renewable resource use and an alignment with a global transition toward a low-carbon electric sector. In this paper, four future UK grid mix scenarios with increased photovoltaic (PV) installed capacity are assessed and compared to a benchmark “Low PV” scenario, from 2016 to 2035. The complexity of the issue requires a multi-disciplinary approach to evaluate the availability of net energy, environmental aspects and technical performance. Hence, the comparison between scenarios includes short-term and long-term energy metrics as well as greenhouse gas (GHG) and technical metrics. Also, the paper considers the viewpoints offered by both an “integrative” and a “dynamic” approach to net energy analysis. Results for all five analysed scenarios indicate that increased PV deployment will not be detrimental to the UK grid performance from the points of view of a wide range of system-level technical (% renewable energy curtailment to ensure grid stability), energy (energy return on investment and non-renewable cumulative energy demand) and environmental (greenhouse gas emissions) metrics.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}

@article{a671d80d2f284e7a9213d8759446fc0ab,

title = {What does the Paris Climate Change Agreement mean for local policy? Downscaling the remaining global carbon budget to sub-national areas.},

author = {Jaise Kuriakose and Christopher Jones and Kevin Anderson and Carly McLachlan and John Broderick},

doi = {10.1016/j.rset.2022.100030},

issn = {2667-095X},

journal = {Renewable and Sustainable Energy Transition},

publisher = {Elsevier BV},

abstract = {Following high profile United Nations climate summits in Glasgow and Paris, sub-national regions and cities are increasingly seeking to set climate targets and policies in line with the Paris Agreement’s goals. Downscaled carbon budgets are a useful framework for setting local mitigation targets related to a specific global temperature change. However, doing so presents a range of methodological issues, including: choices on the appropriate goals to set, the scope of emissions and sectors, the allocation approaches to apply, whether offset credits and/or carbon dioxide removals are acceptable and, if so, to what extent. This paper details a novel and transparent methodology for downscaling a Paris-aligned global carbon budget to sub-national areas, focusing on emissions from energy (power, heat, cooling, surface transport and industry). The effects of different global carbon budgets, various net zero targets and allocation methods on the size of sub-national budgets and associated mitigation rates are explored. The resulting budgets and annual emission reduction rates vary significantly, reflecting the implications of both high-level methodological choices and local factors, including economic activity, energy-system structure and population. Recent historical emissions (grandfathering) are found to be more appropriate for allocating national carbon budgets to sub-national areas than capability or egalitarian allocations. In the UK case study presented, adopting a grandfathering approach, the annual mitigation rates range from 7% to 16% between different sub-national areas. The analysis concludes that establishing agreed sub-national allocation approaches and boundaries are key to developing coherent national strategies consistent with the Paris Agreement’s temperature and equity commitments.},

keywords = {},

pubstate = {published},

tppubtype = {article}

}