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Energy security and climate change are among the top priority challenges for Turkey. High dependency on imported resources jeopardizes the economy, especially with high currency rate and conflicts in neighboring countries from where Turkey imports its energy. Besides, Turkey has already started to experience the impacts of climate change such as increasing temperature along with drought. Floating photovoltaics have proven themselves to be quite efficient in energy production, with evaporation reduction as a positive externality. The purpose of this article is to reveal the possible capacity of floating photovoltaics on constructed water reservoirs of Turkey and draw policy perspectives against existing or anticipated challenges. A total of 4,003 reservoirs were analyzed based on different water surface coverage scenarios. The results of the study proposed 125 TWh electricity generation, slightly above 40% of the nation-wide electricity demand, when 10% of suitable reservoirs were covered. This generation would be highly instrumental in reducing energy dependency and substituting renewables for conventional resource uses. Avoided CO 2 , thanks to this substitution, was calculated to be 77.1 Mton equivalent. This would obviously be favorable in light of the carbon emission reduction policy of the country and Paris Agreement requirements. Moreover, 1,242.1 hm3 freshwater was assessed to save resources from evaporation loss, which would help to mitigate the climate change pressure on water resources. • Turkey is 74% dependent to import energy resources. • A model proposing suitable reservoirs for floating photovoltaic is presented. • 125 TWh electricity can be generated if 10% of the reservoir surfaces are covered. • Water saving is 1,242 hm3: enough to supply 15 M people or hydroelectric as $32.3 M. • 77.6 million tons CO 2 equivalent is avoided. [ABSTRACT FROM AUTHOR]

The present article sets out to examine the connection between energy transition and factors associated with renewable energy sources, buildings and other sectors, placing emphasis on France. The methodology includes: Collection of scholarly writings, classification, identification of research questions, bibliographic analysis, identification of important findings, discussion. The results of a study (EDF, Le nucléaire en chiffres) demonstrated that, in 2019, around 80% of the electricity production from nuclear energy (in France) was provided by 4 regions: Auvergne-Rhône-Alpes , Grand Est , Centre-Val de Loire , Normandie. France has a high dependence on nuclear power generation and, for this reason, renewable-energy penetration is an imperative part of the French energy transition. Numerous studies show that energy transition requires actions based on burgeoning and avant-garde technologies, and effective policies. Moreover, energy transition poses challenges: decisions on nuclear power plants, sustainable development of small-island economies, etc. A discussion on the energy transition in Corsica (France) is also provided. Regarding the French overseas territories Corse (Corsica), Guadeloupe , Martinique , Guyane , Mayotte , Réunion , the findings of a study (Rakotoson and Praene, 2017) demonstrate that thanks to renewable energy sources/network interconnection, Corsica and French Guiana have lower emissions in comparison to the other territories: 0.505 and 0.373 kg CO 2.eq /kWh e , respectively. • The role of renewable energy sources in energy transition has been analysed. • Factors related to buildings, industry, etc. have been discussed (emphasis: France). • France, 2019.→ ≈ 80 % of the nuclear electricity generation was provided by 4 regions • There are challenges such as energy storage and decisions on nuclear plants. • Corsica and French Guiana: emissions 0.505 and 0.373 kg CO 2.eq /kWh e , respectively. [ABSTRACT FROM AUTHOR]

The energy sector has a vital role in climate change mitigation. In Brazil, the electricity generation sector is strongly dependent on hydropower generation, but thermoelectricity contribution has increased leading to a more carbon-intensive electricity mix. This trend will be aggravated with the expected significant increase in the electricity demand until 2050 and with the potential limitation of hydropower generation expansion due to environmental constraints. The extent of the role of solar power to overcome these challenges in the future has been hidden by energy modelling assumptions. A review on how solar energy has been considered in different models, was performed. The research further assessed the relevance of assumptions by developing an optimization model to explore the cost-effectiveness of solar electricity large-scale deployment up to 2050. The work found that most published solar energy assessments based on long-term energy modelling for Brazil currently are not updated regarding several assumptions, leading to models results where solar appears with a marginal role. The energy modeling exercise shows solar PV is cost-effective for Brazil, providing more than 36% of total electricity in 2050. This is a different conclusion from the energy and power modeling exercises conducted until now, where solar deployment has been underestimated. • The work assesses how energy model inputs have affected solar cost-effectiveness for Brazil. • Assumptions on hydropower expansion and technology costs critically affect solar cost-effectiveness. • Energy model exercises have underestimated the potential of solar energy in Brazil. • Solar energy may have an important role in the future Brazilian power sector. [ABSTRACT FROM AUTHOR]

Decarbonizing electricity generation through deployment of renewable technologies such as wind and solar is a key component of many climate change mitigation efforts. With increasing penetrations, the need to manage variability in renewable generation becomes critical. However, renewable variability is often poorly represented in energy planning studies which focus on energy and capacity adequacy. In this study, we used a hybrid capacity expansion and dispatch model with explicit inclusion of ramping and regulation services to examine balancing requirements in a decarbonizing electricity system. We find that ramping and regulation services needed for management of variable renewables alter the optimal mix of generation and transmission capacity relative to simpler planning models. In particular, we find enhanced value in expanding transmission capacity to access flexibility. • Representing short-term constraints in long-term energy models changes the outcome. • Flexibility is a key constraint in systems with high penetrations of renewables. • Interregional transmission can help provide system flexibility. [ABSTRACT FROM AUTHOR]

Whether an enormous untapped hydropower resource should be utilized domestically by heavily electrifying energy end-uses or should be exported to neighboring countries is often debated in Nepal. This study attempts to bring both policy options together and justifies with evidence the need to integrate end-use electrification and cross-border electricity trade policies in the energy transformation of Nepal. We found out that Nepal will continue to import electricity till 2027 to meet its electricity demand throughout the year though it has already started exporting its surplus electricity during the wet season because of the full availability of run-of-river type hydropower. The run-of-river will continue to dominate Nepal's least-cost generation mix with a two-thirds share resulting in considerable surplus electricity during the high-flow season. Such surplus will exceed one-third of its total energy generation capacity in long-run in all end-use electrification scenarios (low to high). Nepal can use its existing cross-border electricity trade mechanism to sell its surplus electricity and can generate revenue of 67 billion USD in the high electrification scenario, which, combined with savings from fossil fuel import savings, can provide 85 % of total electricity generation investment needs. [ABSTRACT FROM AUTHOR]

• Develop an energy system optimization model with shared autonomous vehicles (SAVs). • Analyze ten scenarios to explore the economic and climate change impacts of SAVs. • SAVs lower costs and carbon emissions, even if they induce significant additional VMT. • This is primarily because a transition to SAVs accelerates vehicle electrification. • Synchronizing electric SAV charging with renewable power output has large benefits. The climate change impacts of the anticipated growth in shared autonomous vehicles (SAVs) are highly uncertain due to competing mechanisms whose magnitudes are difficult to estimate. On the one hand, SAVs could reduce greenhouse gas emissions by driving more efficiently, avoiding traffic congestion, accelerating adoption of alternative fuel vehicles, and charging in alignment with renewable electricity generation. On the other hand, SAVs could induce more vehicle miles traveled (VMT) by lowering the time cost of travel and allowing non-drivers to travel more by car. In this study, we develop an energy system optimization model that integrates the electricity and transport sectors, computes endogenous technology adoption, and distinguishes SAVs from privately owned vehicles (POVs) to explore the contributions of SAVs to climate change mitigation. Our results show that widespread SAV adoption lowers costs and emissions, and that these desirable outcomes remain true even if SAVs induce double the VMT of the POVs they replace. SAVs dramatically accelerate the market penetration of electric vehicles. The environmental and economic benefits of this electrification trend are larger if electric SAV charging can be optimally aligned with renewable electricity generation. Especially in the short to medium term, SAV adoption can be a more impactful lever than a carbon tax for decarbonizing vehicle travel. [ABSTRACT FROM AUTHOR]

This paper assesses the evolution of India's power sector to 2050 and identifies crucial low carbon technologies to meet its NDC and long-term climate change mitigation targets under various carbon emission rights allocation schemes using a multi-region global energy systems model TIAM-UCL where India is modelled as a separate region. Six scenarios were developed – reference case, NDC, global 2 °C and three scenarios where CO 2 emissions of all model regions converged in 2050 based on criteria of GDP/capita, emissions intensity of GDP and per capita emissions. The analysis shows that emission rights allocation schemes influence the total energy system development costs, long-term electricity generation requirements, and share of renewables especially solar PV generation to meet the 2 °C target. The model runs also show that solar-PV is the single most important generation technology for decarbonisation of India's power sector. Limiting the share of solar-PV generation can lead to 20% reduction in total electricity generation and increase system costs substantially for 2050. Further, the results also indicate that India may have 200–215 GW of stranded coal generation assets in 2050 in the low carbon scenarios. Our analysis suggest that India is one of those countries which are at the development stage and also highly risked with the lock-in in carbon emitting infrastructure especially coal-based generations unless action taken in the near-term. • Solar-PV is the most important technology for decarbonisation of electricity sector in India requiring 800GW-1100GW by 2050. • Stranded assets of coal power plants could be a real threat to the financial health of the power sector. • Early introduction of CCS for the power sector in India can significantly reduce the cost of overall emissions reductions. • India is one of those countries which are highly risked with the lock-in in carbon emitting infrastructure. [ABSTRACT FROM AUTHOR]

Water consumption in thermoelectric and hydropower plants in China increased from 1.6 and 6.1 billion m 3 , respectively, to 3.8 and 14.6 billion m 3 from 2002 to 2010. Using the concept of virtual water, we attribute to different electricity users the total water consumption by the electric power sector. From 2002 to 2010, virtual water embodied in the final consumption of electricity (hereinafter referred to as VWEF) increased from 1.90 to 7.35 billion m 3 , whilst virtual water in electricity used by industries (hereinafter referred to as VWEI) increased from 5.82 to 11.13 billion m 3 . The inter-provincial virtual water trades as a result of spatial mismatch of electricity production and consumption are quantified. Nearly half (47.5% in 2010) of the physical water inputs into the power sector were virtually transferred across provincial boundaries in the form of virtual water embodied in the electricity produced, mainly from provinces in northeast, central and south China to those in east and north China. Until 2030, VWEF and VWEI are likely to increase from 5.27 and 14.89 billion m 3 to 7.19 and 20.33 billion m 3 , respectively. Climate change mitigation and water conservation measures in the power sector may help to relieve the regional pressures on water resources imposed by the power sector. [ABSTRACT FROM AUTHOR]

Transitioning electricity generation sectors to renewable energy is a necessary element of climate change mitigation but a challenging one with years of technical and social lock-in creating considerable inertia and a pace of change insufficient to meet the task. Transition management has emerged as a promising approach to proactively manage and accelerate transitions in sectors like energy and water and has the potential to do so in manner that would help secure energy justice. However, the approach has been criticised for ignoring the political dynamics of transitions, risking procedural and recognition injustice for traditional energy production regions while increasing opposition to a transition. This paper uses a qualitative case study approach to understand how a transition to renewable energy generation could be achieved in a way that secures energy justice for traditional energy production regions like those of Gladstone in the Australian state of Queensland. The paper augments the transition management approach with the “just transitions” concept, which has emerged from labour movements as a means to mitigate negative impacts on workers and communities in traditional energy production regions, to create a “Just Transition Management” framework that is applied as a diagnostic tool to the case study. While results suggest a transition is imminent within Queensland, a lack of: consistent, supportive federal policy; long-term visions, and a clear process leaves it at risk of being captured by the powerful incumbent resources sector utilising an “environment vs. jobs” narrative. Yet, the results also suggest that adopting a just transition management approach has the potential to successfully resist the influence of the resources sector, by providing cheap, secure renewable energy and supporting affected workers into roles in the renewable energy sector using a reflexive, representative network governance approach. Data analysis reveals how the application of just transition principles has already engaged communities and unions that were previously sceptical of renewable energy. Overall, this study suggests that the just transition management framework assists in identifying the political barriers to transitions and energy justice more broadly, while also providing a management approach which creates powerful niche actor-networks to counter the narratives and influence of the incumbent resource sector. Thus it could support successful transitions that achieve the distributional, recognition and procedural justice needed for energy justice globally. [ABSTRACT FROM AUTHOR]

Urban environments in Latin America must begin decarbonizing their activities to avoid increasing greenhouse gases (GHGs) emissions rates due to their reliance on fossil fuel-based energy to support economic growth. In this context, cities in Latin America have high potential to convert sunlight into energy. Hence, the main objective of this study was to determine the potential of electricity self-sufficiency production and mitigation of GHG emissions in three medium-sized cities in Peru through the revalorization of underutilized rooftop areas in urban environments. Each city represented a distinct natural area of Peru: Pacific coast, Andean region and Amazon basin. More specifically, photovoltaic solar systems were the technology selected for implementation in these rooftop areas. Data on incident solar energy, temperature and energy consumption were collected. Thereafter, ArcGis10.3 was used to quantify the total usable area in the cities. A series of correction factors, including tilt, orientation or roof profiles were applied to attain an accurate value of usable area. Finally, Life Cycle Assessment was the methodology chosen to calculate the reduction of environmental impacts as compared to the current context of using electricity from the regional grids. Results showed that the cities assessed have the potential to obtain their entire current electricity demand for residential, commercial and public lighting purposes, augmenting energy security and resilience to intermittent natural disasters, with the support of decentralized storage systems. This approach would also translate into substantial reductions in terms of GHG emissions. Annual reductions in GHG emissions ranged from 112 ton CO 2 eq in the city of Ayacucho to over 523 kton CO 2 eq in Pucallpa, showing that cities in the Amazon basin would be the ones that benefit the most in terms of climate change mitigation. [ABSTRACT FROM AUTHOR]

To ensure the use of water today does not damage the prospects for its use by future generations, there is need to understand long-term water demand and supply through energy production, conversion, and use. This study aims to develop an integrated framework to assess the long-term impacts of climate change scenarios on water requirements and greenhouse gas (GHG) emissions. The framework includes the integration of the Water Evaluation And Planning model (WEAP) and the Long-range Energy Alternative Planning Systems model (LEAP). As many countries are planning to move towards a cleaner electricity grid to mitigate climate change, this work attempts to present the impact of various scenarios on water demand, GHG emissions, and cost effectiveness. This is done by conducting a case study of the western Canadian province of Alberta where more than 85% of electricity is generated by fossil fuels. This paper provides a comprehensive overview of nine integrated LEAP-WEAP climate change scenarios for the years 2015–2050 by forecasting water consumption and greenhouse gas emissions from the power sector. The economic aspects of the developed scenarios are discussed in the form of a cost curve that shows the GHG saving potential, water use, and GHG mitigation costs for each scenario. For the Business-As-Usual (BAU) scenario (coal power phase out by 2030), GHG emissions and water demand will fall by 44% and 34%, respectively, in 2030. The integrated results show that the scenarios will mitigate carbon emissions but will result in higher water consumption, which will directly affect water resources in the region. Because of the high investment cost to install the considered renewable power plants in the climate change scenarios, the cost of mitigating carbon emissions in the power sector is high. Early coal-to-gas power plant conversion is the only scenario that is expected to save water (67 million m 3 ) and reduce emissions (40 million tonnes of CO 2 eq.) and be cost effective ($68/tonne of CO 2 eq.). These LEAP-WEAP model results can help create awareness among policy makers to understand the water-energy demand and supply relationship in a quantifiable way. [ABSTRACT FROM AUTHOR]

Water is a prime element both for sustaining life on Earth and for complex human activity. In 2015 in Romania the average electricity production was of 7343 MW h and the average consumption was of 6590 MW h. The average hydropower generated was of 1894 MW h, which is equal to 26% of the total production. In this paper, we aim at reviewing the hydropower system in Romania from its beginnings, in 1884, to its present development. The first hydropower plant in Romania was in Sinaia and had an installed capacity of 4×250 kW. Now, Romania has more than 200 HPPs, with a total installed capacity of 6.443 MW. In Romania, hydropower is the first main source of energy among RES, followed by wind energy. Between 1950 and 1990 were built 115 hydropower stations. This period is characterized by the construction of most of the hydroelectric power plants in Romania, including the largest. The development of the hydro potential has begun in Bistrița basin. After 1990, in the transition period, after the fall of communism, the number of installed hydropower plants decreased, by 2010 totaling an installed capacity of only 838 MW, which means less than 14% of what was done before 1990. About 54% of Romania's hydropower potential is now arranged, and there are plans to reach 63.5% by 2025. The largest artificial lake of Romania is Lake Iron Gates I (Porțile de Fier I), constructed between 1964 and 1972 behind a 60 m’ dam. Iron Gate I rank position 52 out of 66, in the list of largest hydroelectric power stations in the world. Iron Gates I system is one of the largest hydro constructions in Europe and the largest on the Danube. [ABSTRACT FROM AUTHOR]

Biomass plays a dual role as an energy source and a solution for climate change mitigation. There are complexities surrounding decentralized electricity generation, and Ghana could not achieve its 10% renewable energy target in 2020. The paper assesses the greenhouse gas mitigation potential and economic impact of electricity from major food crop residues subjected to anaerobic digestion technology in 16 regions and 88 districts in Ghana from 2017 to 2020. Buswell equation was applied to calculate the biogas and methane yield. The environmental impact assessment was expressed as global warming potential, and the economic feasibility was conducted. The results showed that crop residues' annual theoretical and technical potential was 28.92 Mt and 17.24 Mt. The top four residues with the largest share of technical potential were maize (5.41 Mt), yam (3.58 Mt), plantain (3.05 Mt) and cassava (2.39 Mt). Biogas and electricity potentials were 1,912.74 Mm3 and 3,068.34 GWh, which could offset 15.56% of electricity consumption in Ghana. The Ashanti (478.18 GWh), Eastern (430.20 GWh), Bono East (318.29 GWh) and Northern (314 GWh) regions demonstrated the highest electricity potential. Ghana could generate the highest electricity potential of 46.52 GWh in the districts and a minimum potential of 0.89 GWh annually. Power generation potential from anaerobic digestion had a diesel displacement capacity of 923.35 × 10 6 L with a GHG emissions reduction of 2,507.35 kt CO 2 eq. The largest GHG reduction potential was 38.15 kt CO 2 eq at the district level. The findings show that the project is economically viable, with an average net present value of $ 10,105,904 per region and an electricity cost of $ 0.0321/kWh. The study provides critical insights to policymakers and industry developers for decentralized biomass-based electricity generation in Ghana. • A sustainable crop residue assessment is conducted in Ghana. • The total biogas-based electricity is 3,068.34 GWh. • Ashanti region has high electricity (478.18 GWh) than Greater Accra (9.82 GWh). • The total GHG mitigation is estimated as 2507.35 kt CO 2 eq. • The project is economically viable at a cost of $ 0.0321/kWh. [ABSTRACT FROM AUTHOR]

Carbon capture and storage (CCS) is broadly understood to be a key mitigation technology, yet modeling analyses provide different results regarding the applications in which it might be used most effectively. Here we use the Global Change Assessment Model (GCAM) to explore the sensitivity of CCS deployment across sectors and fuels to future technology cost assumptions. We find that CCS is deployed preferentially in electricity generation or in liquid fuels production, depending on CCS and biofuels production cost assumptions. We consistently find significant deployment across both sectors in all of the scenarios considered here, with bioenergy with CCS (BECCS) often the dominant application. As such, this study challenges the view that CCS will primarily be coupled with power plants and used mainly in conjunction with fossil fuels, and suggests greater focus on practical implications of significant CCS and BECCS deployment to inform energy system transformation scenarios over the 21st century. [ABSTRACT FROM AUTHOR]

Transformation of the energy sector’s power generation mix is needed to contain global mean temperature rise to no more than 2 °C above the pre-industrial level. Because the power sector is also a dominant direct and indirect consumer of water, it is vital to understand current and likely future trends in power sector water consumption. In this paper, we use an input-output based hybrid approach to study the direct and indirect impacts on water consumption from power mix adjustment in the world’s seven largest emitting economies under multiple cost-effective mitigation pathways toward the 2 °C target. Although different pathways exist, we discovered generally increases in water consumption of power sector under the long-term 2 °C target compared with no-climate-policy pathways, especially for China and India. Fulfilling the Intended National Determined Contributions (INDCs) could decouple direct water consumption and electricity output for most regions but may result in increases of indirect water consumption in China. This paper suggests that in the light of geographically uneven water scarcity, more comprehensive evaluation of both the direct and indirect water demands of the power sector is demanded when considering climate policies relevant to significant structural and technological adjustments in power sector. [ABSTRACT FROM AUTHOR]

Infrastructure for heat provision in the built environment needs to change remarkably to support lowering carbon emissions and achieving climate mitigation targets before 2050. We propose a computational approach for finding a mix of heat options per neighbourhood that minimises cumulative carbon emissions between 2030 and 2050, referred to as committed emissions, while at the same time adhering to technological constraints at both the household and neighbourhood scales. To establish this approach, we integrated bottom-up heat demand modelling at neighbourhood scale with a mixed-integer non-linear optimisation problem. Nine scenarios with different pathways for the insulation of buildings and the decarbonisation in electricity generation were considered and applied to three neighbourhoods in the city of Amsterdam, the Netherlands. The results show that (i) the committed emissions are ten times lower between 2030 and 2050 in scenarios in which ambitious measures are taken for the insulation of buildings and the decarbonisation in electricity generation, (ii) only in these 'ambitious scenarios' low temperature heat systems, such as heat pumps and low temperature heat networks, are optimal solutions for minimising committed emissions, (iii) if less ambitious insulation and decarbonisation measures are taken, high temperature heat options can be part of the heat mix with lowest committed emissions, and (iv) the minimum heat density for low temperature heat networks is not always achieved, creating risks for carbon lock-ins when applying these heat networks. Our results clearly indicate that pathways for the retrofitting of buildings and the decarbonisation in electricity generation need to be taken into account jointly when designing renewable and low-carbon heat systems to optimally reduce carbon emissions towards 2050 and reduce future carbon lock-ins. • Bottom-up heat demand models enable testing spatial heat system requirements. • Power supply decarbonisation and building insulation characterise ambitious policies. • Hybrid or low temperature heat systems are optimal solutions for ambitious policies. • Ambitious decarbonisation policies can lower committed emissions tenfold. • Heat networks can cause a carbon lock-in due to the needed minimum heat density. [ABSTRACT FROM AUTHOR]

Switzerland and Europe are currently at a crossroads with respect to its electricity policy. Several existing nuclear and fossil fuel power plants are to be retired in the coming years. Meanwhile, ambitious carbon dioxide (CO 2 ) emission reductions are envisaged, which could penalise fossil power plants and encourage investments in renewable-based electricity generation. Switzerland and a few other countries in Europe have decided to phase-out their nuclear capacity, thereby removing a low-carbon source of electricity in the medium- to long-term future. In order to understand possible electricity transition pathways for Switzerland, electricity supply options for Switzerland and its four neighbouring countries namely Austria, France, Germany and Italy are analysed to assess non-nuclear alternatives under a stringent climate mitigation policy. The cross border Swiss TIMES electricity model (CROSSTEM), a cost optimisation framework with a long time horizon and an hourly temporal resolution, is used for this analysis. In the absence of any CO 2 emission reduction targets, gas-based generation supplemented by electricity imports is the cost-effective alternative to nuclear for Switzerland. For a low carbon electricity system, natural gas based generation with Carbon Capture and Storage (CCS), complemented by an accelerated investment in renewable generation is required. Traditional electricity trade patterns have to be revised, with significant increases in cross-border interconnector capacities necessary to transfer electricity to Switzerland from countries with abundant renewable resources such as Germany and Italy. The average cost of electricity in a decarbonised electricity sector would increase in the range of 30–120% by 2050 compared to today, depending on the scenario assumptions. The availability of CCS technology and the requirement for electricity storage are particularly important to achieve a complete decarbonisation of the electricity sector with a nuclear phase-out. [ABSTRACT FROM AUTHOR]

A rapid decarbonization of the electricity system is urgently required for the Paris Agreement objectives to stand a reasonable chance of being met. While state-owned power companies (SPCs) are the dominant firm type in the global electricity sector, representing nearly two thirds of global electric power generation capacity, most climate policy literature focuses on private sector companies when analyzing decarbonization interventions. SPCs' distinct corporate governance structures, objectives, relationships with government, and sources of finance, however, can be markedly different from those of private companies. Here, we develop a framework for analyzing the extent to which common and divergent features of SPCs, and the markets in which they operate, affect their relationship to government interventions on decarbonization. We also consider the implications of these relationships for the effective implementation of sector-wide decarbonization strategies. We then apply this framework using a comparative case study analysis of six major SPCs, and highlight how differences in their agency, motivation, capacity, and market exposure may result in different potential responsiveness to government regulatory, policy and market interventions on decarbonization. We generalize these findings by developing four SPC archetypes and illustrate how they might respond differently to government interventions targeting decarbonization. Our analysis posits that SPCs can, under the guidance of governments pursuing ambitious climate policy, be more effective vehicles for decarbonization relative to private sector companies, particularly when they operate with a high degree of operational independence, are insulated from competitive pressures, and have the financial and technical capacity to invest in the decarbonization of their asset base. Similarly, market-wide policy interventions, such as carbon pricing mechanisms, could in practice be less effective interventions with respect to SPCs than their private counterparts when the SPC is ill-equipped to translate these incentives into decarbonization action because it is mandated to pursue supplementary objectives other than profit maximization alone. Ultimately, governments will need to step up their climate action to achieve carbon neutrality. SPCs can, and where they are major market players, must be key actors in driving decarbonization when the appropriate interventions are utilized and therefore deserve significantly more attention in the climate policy debate. • State-owned enterprises are central to power sector decarbonization. • Comparative case studies yield useful state-owned power company archetypes. • Market-based climate policies are not always effective in state-led power markets. • Policy targeting state-owned enterprises can accelerate power sector mitigation. [ABSTRACT FROM AUTHOR]

Abstract: The implementation of climate change mitigation strategies may significantly affect the current practices for electricity network operation. Increasing penetration of renewable energy generation technologies into electricity networks is one of the key mitigation strategies to achieve greenhouse gas emission reduction targets. Additional climate change mitigation strategies can also contribute to emission reduction thereby supplementing the renewable energy generation participation, which may be limited due to technical constraints of the network. In this paper, the penetration requirements for different renewable energy generation resources are assessed while concurrently examining other mitigation strategies to reduce overall emissions from electricity networks and meet requisite targets. The impacts of climate change mitigation strategies on the demand and generation mix are considered for facilitating the penetration of renewable generation. New climate change mitigation indices namely change in average demand, change in peak demand, generation flexibility and generation mix have been proposed to measure the level of emission reduction by incorporating different mitigation strategies. The marginal emissions associated with the individual generation technologies in the state of New South Wales (NSW) are modelled and the total emissions associated with the electricity grid of NSW are evaluated. [Copyright &y& Elsevier]

Abstract: This study investigates the partial correlations between the share of new renewable electricity in a country and income, energy security and climate change mitigation. For the purpose of this paper, new renewables refer to the electricity generating technologies that have not yet reached grid-parity (e.g. wind, solar). The author proposes a measure of energy security depending on the role of inputs (coal and natural gas) in electricity generation as well as a measure of a country's potential to mitigate climate change based on the quantity of fossil-based electricity generated per capita. Findings from 2007, 2008 and 2009 data on 107 middle and high-income economies show that rich countries relying on coal imports to generate their power, are also those with the highest shares of electric power from new renewables. [Copyright &y& Elsevier]

Abstract: Globally, electricity generation accounts for a large and potentially growing water demand, and as such is an important component to assessments of global and regional water scarcity. However, the current suite—as well as potential future suite—of thermoelectric generation technologies has a very wide range of water demand intensities, spanning two orders of magnitude. As such, the evolution of the generation mix is important for the future water demands of the sector. This study uses GCAM, an integrated assessment model, to analyze the global electric sector''s water demands in three futures of climate change mitigation policy and two technology strategies. We find that despite five- to seven-fold expansion of the electric sector as a whole from 2005 to 2095, global electric sector water withdrawals remain relatively stable, due to the retirement of existing power plants with water-intensive once-through flow cooling systems. In the scenarios examined here, climate policies lead to the large-scale deployment of advanced, low-emissions technologies such as carbon dioxide capture and storage (CCS), concentrating solar power, and engineered geothermal systems. In particular, we find that the large-scale deployment of CCS technologies does not increase long-term water consumption from hydrocarbon-fueled power generation as compared with a no-policy scenario without CCS. Moreover, in sensitivity scenarios where low-emissions electricity technologies are required to use dry cooling systems, we find that the consequent additional costs and efficiency reductions do not limit the utility of these technologies in achieving cost-effective whole-system emissions mitigation. [Copyright &y& Elsevier]

Abstract: This study uses a hybrid Life Cycle Assessment approach to evaluate the environmental impacts of large-scale deployment of Carbon dioxide Capture and Storage (CCS) in coal and natural gas based electricity generation, based on IEA scenarios. For the Baseline scenario, all impact categories would increase 2–3-fold in 2050 from 2005 levels. Green House Gas (GHG) emissions are found to decrease by ∼40% in ACTmap scenario and by ∼75% in more CCS-intensive BLUEmap scenario. These climate mitigation scenarios also show significantly reduced impacts of acidification, particulate matter formation and human toxicity, suggesting the existence of co-benefits. For eutrophication, all scenarios indicate substantial increases, but the increases are largest in the Baseline scenario. For photochemical oxidant formation, only the mitigation scenarios manage to stabilize this impact from fossil fuel based power production. This study does not assess the impact of alternative power generation or energy efficiency technology that replaces part of the fossil fuel power in the mitigation scenarios. [Copyright &y& Elsevier]

Abstract: At Copenhagen, the developed countries agreed to provide up to $100bn per year to finance climate change mitigation and adaptation by developing countries. Projects aimed at cutting greenhouse gas (GHG) emissions will need to be evaluated against dual criteria: from the viewpoint of the developed countries they must cut emissions of GHGs at reasonable cost, while host countries will assess their contribution to development, or simply their overall economic benefits. Co-benefits of some types of project will also be of interest to host countries: for example some projects will contribute to reducing air pollution, thus improving the health of the local population. This paper uses a simple damage function methodology to quantify some of the health co-benefits of replacing coal-fired generation with wind or small hydro in China. We estimate the monetary value of these co-benefits and find that it is probably small compared to the added costs. We have not made a full cost-benefit analysis of renewable energy in China as some likely co-benefits are omitted from our calculations. Our results are subject to considerable uncertainty however, after careful consideration of their likely accuracy and comparisons with other studies, we believe that they provide a good first cut estimate of co-benefits and are sufficiently robust to stand as a guide for policy makers. In addition to these empirical results, a key contribution made by the paper is to demonstrate a simple and reasonably accurate methodology for health benefits estimation that applies the most recent academic research in the field to the solution of an increasingly important problem. [Copyright &y& Elsevier]

Abstract: Gases like CH4, CO2 and H2 may play a key role in establishing a sustainable energy system: CH4 is the least carbon-intensive fossil energy resource; CO2 capture and storage can significantly reduce the climate footprint of especially fossil-based electricity generation; and the use of H2 as energy carrier could enable carbon-free automotive transportation. Yet the construction of large pipeline infrastructures usually constitutes a major and time-consuming undertaking, because of safety and environmental issues, legal and (geo)political siting arguments, technically un-trivial installation processes, and/or high investment cost requirements. In this article we focus on the latter and present an overview of both the total costs and cost components of the distribution of these three gases via pipelines. Possible intricacies and external factors that strongly influence these costs, like the choice of location and terrain, are also included in our analysis. Our distribution cost breakdown estimates are based on transportation data for CH4, which we adjust for CO2 and H2 in order to account for the specific additional characteristics of these two gases. The overall trend is that pipeline construction is no longer subject to significant cost reductions. For the purpose of designing energy and climate policy we therefore know in principle with reasonable certainty what the minimum distribution cost components of future energy systems are that rely on pipelining these gases. We describe the reasons why we observe limited learning-by-doing and explain why negligible construction cost reductions for future CH4, CO2 and H2 pipeline projects can be expected. Cost data of individual pipeline projects may strongly deviate from the global average because of national or regional effects related to the type of terrain, but also to varying costs of labor and fluctuating market prices of components like steel. [Copyright &y& Elsevier]

Abstract: The long-term assessment of new electricity generation was performed for various long-run policy scenarios taking into account two main criteria: private costs and external GHG emission costs. Such policy oriented power generation technologies assessment based on carbon price and private costs of technologies can provide information on the most attractive future electricity generation technologies taking into account climate change mitigation targets and GHG emission reduction commitments for world regions. Analysis of life cycle GHG emissions and private costs of the main future electricity generation technologies performed in this paper indicated that biomass technologies except large scale straw combustion technologies followed by nuclear have the lowest life cycle GHG emission. Biomass IGCC with CO2 capture has even negative life cycle GHG emissions. The cheapest future electricity generation technologies in terms of private costs in long-term perspective are: nuclear and hard coal technologies followed by large scale biomass combustion and biomass CHPs. The most expensive technologies in terms of private costs are: oil and natural gas technologies. As the electricity generation technologies having the lowest life cycle GHG emissions are not the cheapest one in terms of private costs the ranking of technologies in terms of competitiveness highly depend on the carbon price implied by various policy scenarios integrating specific GHG emission reduction commitments taken by countries and climate change mitigation targets. [Copyright &y& Elsevier]

Abstract: In order to take up the twin challenge of reducing carbon dioxide (CO2) emissions, while meeting a growing energy demand, the potential deployment of carbon dioxide capture and storage (CCS) technologies is attracting a growing interest of policy makers around the world. In this study we evaluate and compare national approaches towards the development of CCS in the United States, Canada, Norway, the Netherlands, and Australia. The analysis is done by applying the functions of innovation systems approach. This approach posits that new technology is developed, demonstrated and deployed in the context of a technological innovation system. The performance assessment of the CCS innovation system shows that the extensive knowledge base and knowledge networks, which have been accumulated over the past years, have not yet been utilized by entrepreneurs to explore the market for integrated CCS concepts linked to power generation. This indicates that the build-up of the innovation system has entered a critical phase that is decisive for a further thriving development of CCS. In order to move the CCS innovation system through this present difficult episode and deploy more advanced CCS concepts at a larger scale; it is necessary to direct policy initiatives at the identified weak system functions, i.e. entrepreneurial activity, market creation and the mobilization of resources. Moreover, in some specific countries it is needed to provide more regulatory guidance and improve the legitimacy for the technology. We discuss how policy makers and technology managers can use these insights to develop a coherent policy strategy that would accelerate the deployment of CCS. [Copyright &y& Elsevier]

Abstract: Possible growth paths for new electricity generation technologies are investigated on the basis of an empirical analysis of past penetration rates. Finding and understanding high market penetration scenarios is relevant to formulating climate change mitigation strategies. The analysis shows that under favorable growth conditions, photovoltaics and wind could produce 15% and 25%, respectively, of world electricity by 2050. Under the same assumptions nuclear power could increase to 41% of world electricity. But it is unlikely that all three technology paths could be realized up to these values simultaneously and therefore the penetration rates presented here should be considered as indicative only. The results show that under positive conditions, an embryonic technology could move as a preferred option into a mainstream energy source within half a century. The introduction of growth constraints reflecting, e.g., severe economic, technical, or political limitations could reduce the above numbers by a factor of up to 2–3. The results indicate a decline in the relative year-to-year growth of new technologies when they have higher market shares. A comparison of the results with other short-term and long-term technology scenarios shows satisfactory agreement. [Copyright &y& Elsevier]

• We model CO 2 source-sink matching for decarbonizing India's electricity. • Domestic and Middle East CO 2 storage sites are explored for optimized matching. • International matching with enhanced oil recovery enhances economic feasibility. • CO 2 shipping could expand the potential of CCUS in India's climate mitigation. India is the third largest CO 2 emitter in the world and the ascending trend has not shown clear signs of leveling off. Electricity generation is the most important contributing sector. This paper examines the role of CO 2 capture, utilization and storage (CCUS) in decarbonizing India's electricity. We build a source-sink matching optimization model and unlike previous research, include transport by ship to overseas CO 2 storage sites. We initialize the model with open-source data on power sector emissions and sinks to work out the least-cost solutions for achieving various CO 2 matching scenarios. CO 2 can be captured in fossil-fuel-fired power plants in India, while the utilization and storage could be either within or beyond the country's border. We assess the potential chain of shipping CO 2 to the Middle East for enhanced oil recovery and CO 2 storage. The economics of such international CCUS chains may affect the role of CCUS in India's decarbonization scenarios. We provide first order estimates of costs and conditions to make such a proposition attractive. The model is available with an open-source license and is customizable to include additional sources, onshore and overseas sinks, and shipping terminals. [ABSTRACT FROM AUTHOR]

Addressing climate mitigation while meeting global electrification goals will require major transitions from fossil-fuel dependence to large-scale renewable energy deployment. However, renewables require significant land assets per unit energy and could come at high cost to ecosystems, creating potential conflicts between global climate mitigation and biodiversity conservation. Here, we explore the potential biodiversity implications of alternative future global electrification pathways as depicted under the Shared Socioeconomic Scenarios (SSPs), i.e., alternative trends in societal development. We examined the intersection of high-resolution estimates of global energy densities for ten renewable and conventional technologies with global richness data to estimate technology-specific biodiversity footprints (species per GWh), whereas a Cumulative Biodiversity Impact (CBI) score was used to assess land and biodiversity outcomes of alternative scenarios. Downscaled electricity generation scenarios (2020−2100) were also constrained by alternative land conservation and energy development policies. Unexpectedly, variation among SSPs did not exhibit a clear tradeoff between global climate mitigation and CBI. Rather, CBIs were an outcome of total infrastructure development to meet electricity demand (from population growth and GDP) and the total magnitude of renewable energy development and storage technologies. Renewables assembled along a spectrum from land sharing to sparing. At the land sharing end, biomass-powered electricity from dedicated crops contributed the most to biodiversity impacts due to low energy density, whereas land-sparing technologies (solar) caused more-intense land degradation, but in smaller areas. Our results suggest that local land conservation practices and strategies promoting energy diversification could have greater implications for future biodiversity conflicts than global socioeconomic drivers. • Energy transitions for climate mitigation may incur tradeoffs with biodiversity. • Alternative electrification and land conservation scenarios were assessed. • SSP 5 (high energy) had highest biodiversity impact whereas SSP 3 had lowest. • Highest impacts from large biomass, solar, wind, and hydropower expansion • Land conservation policy more important to conservation than global socioeconomics [ABSTRACT FROM AUTHOR]

The coronavirus pandemic has infected more than 23 million people worldwide by August 2020 along with more than 800,000 deaths. To face this pandemic, a joint effort among different areas has been required. In this context, the correct supply of basic services is the key to enhance the complex circumstance. The operation of the electric power systems is needed to ensure the answer to the situation. Basic services in areas of health, security, food, and communications depend on the electricity supply. Consequently, this paper introduces a multi-objective procedure that enhances the operations of power systems under these circumstances. It considers geographical areas that are affected by coronavirus cases and their effects on the personnel of power plants. To obtain the best combinations of total cost and protection of the workers, lexicographic optimization is implemented. The effectiveness of this approach is studied by solving two test cases: a 6-bus system and the Argentine Electric System with real data about the infection cases. The effects on the electricity generation and transportation stages are studied. The results allow identifying critical areas and proposing corrective actions. The method can reach feasible solutions with a low computational requirement. [Display omitted] • Model studies the impact of the pandemic on the operation of a large-scale systems. • Multi-objective model considers how the pandemic affects different power plants. • It ensures the normal supply by considering health and economic aspects. • Relationship between the reduction of personnel due to infections is studied. • It relates the operation of power plants with the availability of workers. [ABSTRACT FROM AUTHOR]

This article reviews climate change mitigation policies implemented in five major emitting economies: China, the European Union, India, Japan and the United States. It analyses their historical performance in terms of energy system and greenhouse gas emissions indicators. In cases where policies aim to reduce future emissions, their target performance levels are assessed. The review centres on the sectors of electricity generation, passenger vehicles, freight transport, forestry, industry, buildings, agriculture, and oil and gas production. Most focus countries have implemented successful policies for renewable energy, fuel efficiency, electrification of passenger vehicles, and forestry. For other sectors, information is limited or very heterogeneous (e.g. buildings, appliances, agriculture) or there are few comprehensive policies in place (e.g. industry). The article further presents an explorative emissions scenario developed under the assumption that all countries will replicate both the observed trends in sector-level indicators and the trends that policies for future emissions reductions aspire to achieve. It shows that the global replication of sector progress would reduce greenhouse gas emissions by 2030 by about 20% compared to a current policies scenario. All countries analysed would overachieve the emissions reduction targets in their post-2020 climate targets. However, the resulting reduction in global emissions by 2030 would still not be sufficient to keep the world on track for a global cost-effective pathway that keeps temperature increase below 2°C. The findings of this study emphasise the need for transformative policies to keep the Paris Agreement temperature limit within reach. • China, the EU, Japan, India and the USA have effective policies for renewable energy, passenger vehicles, and forestry. • Other sectors are lagging behind in climate change mitigation. • Global replication of sector policies would reduce emissions by 20% in 2030. • This would, however, not close the emissions gap in 2030. • Implied emissions reductions go beyond the Nationally Determined Contributions for all economies analysed. [ABSTRACT FROM AUTHOR]

Accessibility has been conceptualized and applied in different ways, depending on the underlying political objectives. In the context of climate change and ambitious emission reduction targets, environmental concerns have risen high on the political agenda. Existing methods for assessing transport-related environmental impacts typically depend on realized or modeled travel behavior. Many of them do not entail a spatial dimension, ignore the importance of the land use component, lack scenario building capabilities or have limited communication value. Consequently, accessibility analysis and planning could make a valuable contribution towards a low carbon transition, but needs to attune to the specific objective of reducing transport-related greenhouse gas emissions. This paper introduces a novel conceptualization of location-based accessibility, where CO 2 emissions are used as a travel cost in place of time or monetary costs. By identifying and assessing options for interventions in the land use and transport system, carbon-based accessibility instruments might serve a number of potential decision-making purposes related to low carbon mobility planning. Carbon-based accessibility of a business park in the Munich region is analyzed in multiple scenarios to demonstrate the application potential of the method. The experiential application focuses on the effects of changes in vehicle efficiency and occupancy rates of both car and transit, but also compares the resulting carbon-based accessibility levels to alternative sites with the transport system unchanged. Applying carbon-based accessibility instruments to real-world planning issues could enhance strategic decision-making processes in the context of climate change mitigation. • Accessibility instruments need to be attuned to the challenges of climate change. • The proposed method uses CO 2 emissions as a travel cost in location-based accessibility measures. • The accessibility measure is sensitive to changes in occupancy rate, vehicle efficiency, and electricity generation mix. • Carbon-based accessibility might be a useful addition to existing decision-making tools. [ABSTRACT FROM AUTHOR]

Our societies are continuously grappling with how to achieve rapid economic growth while minimizing the challenges of environmental sustainability. In this avenue, numerous studies have contributed towards investigating socio-economic factors and developing policies targeting environmental pressures (EPs). While previous studies have tended to focus on the individual driving forces of EPs, the consideration of the co-benefits and trade-offs among different EPs and policies have been considerably overlooked. In China, previous studies have mostly engaged these issues at the national level and have overlooked the regional socio-economic characteristics – this presents a mismatch between regional policy applications and average national level research findings. Towards this end, this study examines the co-benefits and trade-offs of eight EPs in Zhejiang during the 2007–2015 period. Our findings revealed strict co-benefits in reductions of all eight EPs due to intensity changes as well as trade-offs due to changes in final demand structure and final demand composition. Sectoral results show that only the Non-Ferrous Metal Ores sector has strict co-benefits among all EPs from the production perspective, while eight sectors have strict co-benefits from the consumption perspective mainly including the Mining and Washing of Coal , Ferrous Metal Ores, Electric Power and Heat Power sectors. Our findings suggest important policy implications associated with utilizing co-benefits and avoiding trade-offs for EP mitigation: making full use of all driving forces, strengthening intersectoral coordination, and establishing a joint evaluation mechanism among different sectors. Image 1 • Environmental pressures (EPs) in Zhejiang's socio-economic evolution were studied. • Sectorial level co-benefits and trade-offs of eight EPs in Zheijiang were analyzed. • Strict co-benefits in reducing EPs were observed through intensity changes. • EPs had more trade-offs than co-benefits at the sectorial level. • Mitigation of EPs demand utilization of co-benefits and avoidance of trade-offs. [ABSTRACT FROM AUTHOR]