Pub Date : 2025-01-30DOI: 10.1016/j.egycc.2025.100178
Julia Paletta, Bruno SL Cunha, Rebecca Draeger, Roberto Schaeffer, Alexandre Szklo
Due to the strict remaining carbon budgets, the need to raise the ambition to phase out oil and gas (O&G) production can lead to the cessation of exploration and production (E&P) projects that might become stranded. This study discusses the definition of stranded assets and its misleading interpretations regarding asset compensation. The compensation here pertains to a situation in which O&G upstream activities (exploration, development, or extraction) are stopped without pre-existing provisions for that in contracts. Speculatively speaking, this halt could be justified by the imperative to decarbonize the economy. Compensation methodologies based on valuation approaches and applied to owners of E&P rights are discussed. Findings show that resources and reserves cannot be mandatorily considered assets, as per the accounting definition. Hence, naming them stranded assets could pose a “bias threat” in the selection of a valuation model in the event of compensation. There is a wide gap difference between discounted cash flow (DCF) and asset-based valuation models to compensate for O&G phase-out. The DCF approach leads to values of such magnitude that could challenge State's capacity to promote environmental regulatory changes while asset-based compensation amounts are straighter forward and make O&G phase-out more feasible especially if cancelled at early or later stages.
{"title":"Stranded assets and compensation in oil and gas upstream projects: Conceptual and practical issues","authors":"Julia Paletta, Bruno SL Cunha, Rebecca Draeger, Roberto Schaeffer, Alexandre Szklo","doi":"10.1016/j.egycc.2025.100178","DOIUrl":"10.1016/j.egycc.2025.100178","url":null,"abstract":"<div><div>Due to the strict remaining carbon budgets, the need to raise the ambition to phase out oil and gas (O&G) production can lead to the cessation of exploration and production (E&P) projects that might become stranded. This study discusses the definition of stranded assets and its misleading interpretations regarding asset compensation. The compensation here pertains to a situation in which O&G upstream activities (exploration, development, or extraction) are stopped without pre-existing provisions for that in contracts. Speculatively speaking, this halt could be justified by the imperative to decarbonize the economy. Compensation methodologies based on valuation approaches and applied to owners of E&P rights are discussed. Findings show that resources and reserves cannot be mandatorily considered assets, as per the accounting definition. Hence, naming them stranded assets could pose a “bias threat” in the selection of a valuation model in the event of compensation. There is a wide gap difference between discounted cash flow (DCF) and asset-based valuation models to compensate for O&G phase-out. The DCF approach leads to values of such magnitude that could challenge State's capacity to promote environmental regulatory changes while asset-based compensation amounts are straighter forward and make O&G phase-out more feasible especially if cancelled at early or later stages.</div></div>","PeriodicalId":72914,"journal":{"name":"Energy and climate change","volume":"6 ","pages":"Article 100178"},"PeriodicalIF":5.8,"publicationDate":"2025-01-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143207499","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Carbon pricing is a core pillar in the policy mix required for the transition to carbon neutrality. Carbon pricing raises energy prices and related service costs, but distributes the burden unequally among the population, which though can be mitigated by accompanying compensation schemes. For the example of the Austrian Province of Styria, we analyze the impacts of national carbon pricing for heating and motor fuels. Using the Exact Affine Stone Index (EASI) demand system and applying different definitions of fuel poverty, we compare how five compensation schemes mitigate impacts on fuel poor households. Uncompensated carbon pricing has nearly twice the negative welfare impacts on fuel poor households than on the average Styrian household, in particular if they live in rural regions and if the fuel poverty definition includes transport expenditures. All analyzed compensation schemes achieve similar carbon emission reductions as uncompensated carbon pricing, but additionally reduce inequality and increase overall welfare. In particular, they increase welfare among poor households and dampen the negative welfare impacts of uncompensated carbon pricing on the wealthiest. Accounting for low income in fuel poverty definitions and compensation schemes yields the highest welfare benefits. Price changes in motor fuels are the dominant impact channel, emphasizing the importance of considering transport in the debate on vulnerability to carbon pricing.
{"title":"Welfare and inequality impacts of carbon pricing and compensation schemes on fuel poor households in Styria, Austria","authors":"Veronika Kulmer , Dominik Kortschak , Judith Köberl , Sebastian Seebauer","doi":"10.1016/j.egycc.2025.100177","DOIUrl":"10.1016/j.egycc.2025.100177","url":null,"abstract":"<div><div>Carbon pricing is a core pillar in the policy mix required for the transition to carbon neutrality. Carbon pricing raises energy prices and related service costs, but distributes the burden unequally among the population, which though can be mitigated by accompanying compensation schemes. For the example of the Austrian Province of Styria, we analyze the impacts of national carbon pricing for heating and motor fuels. Using the Exact Affine Stone Index (EASI) demand system and applying different definitions of fuel poverty, we compare how five compensation schemes mitigate impacts on fuel poor households. Uncompensated carbon pricing has nearly twice the negative welfare impacts on fuel poor households than on the average Styrian household, in particular if they live in rural regions and if the fuel poverty definition includes transport expenditures. All analyzed compensation schemes achieve similar carbon emission reductions as uncompensated carbon pricing, but additionally reduce inequality and increase overall welfare. In particular, they increase welfare among poor households and dampen the negative welfare impacts of uncompensated carbon pricing on the wealthiest. Accounting for low income in fuel poverty definitions and compensation schemes yields the highest welfare benefits. Price changes in motor fuels are the dominant impact channel, emphasizing the importance of considering transport in the debate on vulnerability to carbon pricing.</div></div>","PeriodicalId":72914,"journal":{"name":"Energy and climate change","volume":"6 ","pages":"Article 100177"},"PeriodicalIF":5.8,"publicationDate":"2025-01-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143377391","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-01-27DOI: 10.1016/j.egycc.2025.100176
Andrea N. Arias-Sanchez, Kenneth Flores, Han Fu, Thais Betoni, Paul Westerhoff, Sergi Garcia-Segura
The economic, environmental, technological and social development of society are linked with two crucial resources: energy and water. The increasing energy costs and the scarcity of fresh water have caused concern across the globe due to limited access to these resources. Consequently, academia and industry are combining efforts to enhance technological processes, optimize resources, and valorize waste management by improving the water-energy nexus. In this context, brine waters from ocean, brackish groundwater and industrial desalination have been identified as potential waste from which value-added products can be sourced. In this perspective paper, firstly, an overview of the main current treatment methods for brines and their chemical composition is presented. Most processes solely focus on the recovery of water, being over 70 %, with energy consumption from 2 to 100 kWh/m3. The high variability is based upon disposal costs of concentrated brines – with the highest associated with zero liquid discharge (ZLD) plus salt disposal. The salinity, concentration of ions, and chemical oxygen demand (COD) of brines differ depending on their respective sources. Second, the water-energy potential nexus of the water splitting of brines was contextualized. The perspective proposed herein is based on the integration of the production of H2 through water splitting using renewable energy and the subsequent H2 oxidation in a fuel cell to produce energy (recirculated within the process) and water (for drinking or industrial use). Finally, the prospects of electrochemical and photocatalytic technologies for water splitting of brines are outlined. Reactor designs and the influence of brine composition are considered the main aspects to be compared, identifying important advantages and challenges for a sustainable water-energy nexus in the treatment of brines.
{"title":"Perspectives of electrochemical and photocatalytic technologies for the water-energy nexus potential of water splitting of brines","authors":"Andrea N. Arias-Sanchez, Kenneth Flores, Han Fu, Thais Betoni, Paul Westerhoff, Sergi Garcia-Segura","doi":"10.1016/j.egycc.2025.100176","DOIUrl":"10.1016/j.egycc.2025.100176","url":null,"abstract":"<div><div>The economic, environmental, technological and social development of society are linked with two crucial resources: energy and water. The increasing energy costs and the scarcity of fresh water have caused concern across the globe due to limited access to these resources. Consequently, academia and industry are combining efforts to enhance technological processes, optimize resources, and valorize waste management by improving the water-energy nexus. In this context, brine waters from ocean, brackish groundwater and industrial desalination have been identified as potential waste from which value-added products can be sourced. In this perspective paper, firstly, an overview of the main current treatment methods for brines and their chemical composition is presented. Most processes solely focus on the recovery of water, being over 70 %, with energy consumption from 2 to 100 kWh/m<sup>3</sup>. The high variability is based upon disposal costs of concentrated brines – with the highest associated with zero liquid discharge (ZLD) plus salt disposal. The salinity, concentration of ions, and chemical oxygen demand (COD) of brines differ depending on their respective sources. Second, the water-energy potential nexus of the water splitting of brines was contextualized. The perspective proposed herein is based on the integration of the production of H<sub>2</sub> through water splitting using renewable energy and the subsequent H<sub>2</sub> oxidation in a fuel cell to produce energy (recirculated within the process) and water (for drinking or industrial use). Finally, the prospects of electrochemical and photocatalytic technologies for water splitting of brines are outlined. Reactor designs and the influence of brine composition are considered the main aspects to be compared, identifying important advantages and challenges for a sustainable water-energy nexus in the treatment of brines.</div></div>","PeriodicalId":72914,"journal":{"name":"Energy and climate change","volume":"6 ","pages":"Article 100176"},"PeriodicalIF":5.8,"publicationDate":"2025-01-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143137843","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
In alignment with the Paris Agreement's objectives and the global commitment to limit global warming to +2 °C, France is committed to achieving Carbon Neutrality by 2050. To pave the way towards this ambitious goal, France has drawn up a roadmap known as the National Low-Carbon Strategy (NLCS). This paper aims to assess the macroeconomic impacts of the NLCS scenario. We use a Computable General Equilibrium model to assess the economic impacts of an energy transition scenario aiming for Carbon Neutrality in France by 2050. Our simulations show that climate change policies to reach carbon neutrality, including carbon taxation with full redistribution, could lead to an economic dividend. We find an increase in investments and jobs creations in green industries that are much higher than job destruction in fossil fuel intensive industries and energy sectors. Despite higher prices, demand increases, and GDP is higher than in the reference scenario. Ultimately, the energy transition induces a 3.4 % increase in GDP and a 2.8 % increase in employment compared to the baseline scenario in 2050.
{"title":"Macroeconomic effects of achieving Carbon Neutrality in France","authors":"Gaël Callonnec , Hervé Gouëdard , Meriem Hamdi-Cherif , Gissela Landa , Paul Malliet , Frédéric Reynès , Aurélien Saussay","doi":"10.1016/j.egycc.2025.100174","DOIUrl":"10.1016/j.egycc.2025.100174","url":null,"abstract":"<div><div>In alignment with the Paris Agreement's objectives and the global commitment to limit global warming to +2 °C, France is committed to achieving Carbon Neutrality by 2050. To pave the way towards this ambitious goal, France has drawn up a roadmap known as the National Low-Carbon Strategy (NLCS). This paper aims to assess the macroeconomic impacts of the NLCS scenario. We use a Computable General Equilibrium model to assess the economic impacts of an energy transition scenario aiming for Carbon Neutrality in France by 2050. Our simulations show that climate change policies to reach carbon neutrality, including carbon taxation with full redistribution, could lead to an economic dividend. We find an increase in investments and jobs creations in green industries that are much higher than job destruction in fossil fuel intensive industries and energy sectors. Despite higher prices, demand increases, and GDP is higher than in the reference scenario. Ultimately, the energy transition induces a 3.4 % increase in GDP and a 2.8 % increase in employment compared to the baseline scenario in 2050.</div></div>","PeriodicalId":72914,"journal":{"name":"Energy and climate change","volume":"6 ","pages":"Article 100174"},"PeriodicalIF":5.8,"publicationDate":"2025-01-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143137840","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-01-01DOI: 10.1016/j.egycc.2024.100172
Santiago Gonzalez Hernandez, Abby Kirchofer
Hydrogen is anticipated to play a pivotal role in decarbonizing the global energy supply chain, and governments worldwide are implementing policies and incentives to foster the adoption of low-carbon hydrogen technologies. However, the divergent lifecycle carbon intensity (CI) calculation methodologies and sustainability requirements at federal and state levels may inadvertently promote certain low-carbon hydrogen technologies over others due to the CI variability arising from the calculation methodologies. This perspective focuses on key sustainable hydrogen technologies favored by industry leaders for commercial deployment. It offers a comprehensive review of the applicability, challenges, and opportunities associated with these technologies under relevant government incentive programs. The study evaluates published lifecycle CI data for hydrogen production methods including low-temperature water electrolysis, high-temperature water electrolysis, biomass gasification, and steam methane reforming of natural gas with carbon capture and sequestration. Methodologies and requirements from prominent programs such as the California Low Carbon Fuel Standard (LCFS), the US federal clean hydrogen production tax credit (45V), and the EU's renewable energy directive (RED) are compared by the authors. This perspective's analysis contributes valuable insights to the discourse on life cycle assessment (LCA) modeling for low-CI hydrogen. It highlights the discrepancies between key government incentives for hydrogen technologies deemed critical to meeting the world's climate goals.
{"title":"Incentivizing hydrogen: A perspective review of lifecycle analysis methodology disparities affecting hydrogen incentives in policy frameworks","authors":"Santiago Gonzalez Hernandez, Abby Kirchofer","doi":"10.1016/j.egycc.2024.100172","DOIUrl":"10.1016/j.egycc.2024.100172","url":null,"abstract":"<div><div>Hydrogen is anticipated to play a pivotal role in decarbonizing the global energy supply chain, and governments worldwide are implementing policies and incentives to foster the adoption of low-carbon hydrogen technologies. However, the divergent lifecycle carbon intensity (CI) calculation methodologies and sustainability requirements at federal and state levels may inadvertently promote certain low-carbon hydrogen technologies over others due to the CI variability arising from the calculation methodologies. This perspective focuses on key sustainable hydrogen technologies favored by industry leaders for commercial deployment. It offers a comprehensive review of the applicability, challenges, and opportunities associated with these technologies under relevant government incentive programs. The study evaluates published lifecycle CI data for hydrogen production methods including low-temperature water electrolysis, high-temperature water electrolysis, biomass gasification, and steam methane reforming of natural gas with carbon capture and sequestration. Methodologies and requirements from prominent programs such as the California Low Carbon Fuel Standard (LCFS), the US federal clean hydrogen production tax credit (45V), and the EU's renewable energy directive (RED) are compared by the authors. This perspective's analysis contributes valuable insights to the discourse on life cycle assessment (LCA) modeling for low-CI hydrogen. It highlights the discrepancies between key government incentives for hydrogen technologies deemed critical to meeting the world's climate goals.</div></div>","PeriodicalId":72914,"journal":{"name":"Energy and climate change","volume":"6 ","pages":"Article 100172"},"PeriodicalIF":5.8,"publicationDate":"2025-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143137841","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-12-24DOI: 10.1016/j.egycc.2024.100173
Clemens Schneider , Max Åhman , Stefan Lechtenböhmer , Mathieu Saurat
Today's petrochemical industry relies on fossil hydrocarbons, not only for energy purposes but also as feedstock. This use of fossil materials is being challenged by the European Union's target to achieve climate neutrality by 2050. The most affected region in Europe is the cross-border region between Antwerp, Rotterdam and the Rhine-Ruhr area in western Germany, an interconnected petrochemical meta-cluster. Although several defossilisation scenarios for petrochemicals have been developed both at the EU level and for single countries, the effect that an EU-wide transition from fossil to non-fossil feedstock would have on technology routes, feedstock alternatives and final product shares, as well as the resulting locational and geographical consequences are not yet understood. To fill this gap, the paper presents a scenario where the European petrochemical industry transitions away from fossil by 2050 and analyses how the energy supply and the defossilisation of carbon supply will change this industry. With this scenario as a backdrop, a zoom-in shows how the Antwerp-Rotterdam-Rhine-Ruhr Area might evolve technically and spatially. To this end, a techno-economic bottom-up model is employed that derives cost-optimal pathways towards defossilised petrochemical production networks. The analysis shows that a scenario for petrochemicals that achieves full non-fossil feedstock use in the EU by 2050 is very likely to be associated with a significant change not only in the feedstock base but also in the production technologies. The meta-cluster will face major challenges as its current strength in specialty polymers might suffer from cost increases for aromatics and the high energy intensity of the respective polymerisation steps. This requires specific strategies in regard to feedstock and energy supply as well as infrastructure.
{"title":"A defossilised EU petrochemical production system: Consequences for the meta-cluster in the Antwerp-Rotterdam-Rhine-Ruhr Area","authors":"Clemens Schneider , Max Åhman , Stefan Lechtenböhmer , Mathieu Saurat","doi":"10.1016/j.egycc.2024.100173","DOIUrl":"10.1016/j.egycc.2024.100173","url":null,"abstract":"<div><div>Today's petrochemical industry relies on fossil hydrocarbons, not only for energy purposes but also as feedstock. This use of fossil materials is being challenged by the European Union's target to achieve climate neutrality by 2050. The most affected region in Europe is the cross-border region between Antwerp, Rotterdam and the Rhine-Ruhr area in western Germany, an interconnected petrochemical meta-cluster. Although several defossilisation scenarios for petrochemicals have been developed both at the EU level and for single countries, the effect that an EU-wide transition from fossil to non-fossil feedstock would have on technology routes, feedstock alternatives and final product shares, as well as the resulting locational and geographical consequences are not yet understood. To fill this gap, the paper presents a scenario where the European petrochemical industry transitions away from fossil by 2050 and analyses how the energy supply and the defossilisation of carbon supply will change this industry. With this scenario as a backdrop, a zoom-in shows how the Antwerp-Rotterdam-Rhine-Ruhr Area might evolve technically and spatially. To this end, a techno-economic bottom-up model is employed that derives cost-optimal pathways towards defossilised petrochemical production networks. The analysis shows that a scenario for petrochemicals that achieves full non-fossil feedstock use in the EU by 2050 is very likely to be associated with a significant change not only in the feedstock base but also in the production technologies. The meta-cluster will face major challenges as its current strength in specialty polymers might suffer from cost increases for aromatics and the high energy intensity of the respective polymerisation steps. This requires specific strategies in regard to feedstock and energy supply as well as infrastructure.</div></div>","PeriodicalId":72914,"journal":{"name":"Energy and climate change","volume":"6 ","pages":"Article 100173"},"PeriodicalIF":5.8,"publicationDate":"2024-12-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143137664","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
In this study, we considered the case of decarbonizing Ukraine's electricity sector that has significant import dependence, high energy and carbon intensity, and an unprecedented destruction of electricity facilities due to ongoing war. Using a newly built UKRAINE-EXPANSE model, which covers 24 Ukrainian oblasts (regions) and five neighboring countries at high temporal and spatial resolution, we offered four cost-optimal scenarios for the national electricity sector in 2035. Considering the targets of the current National Energy and Climate Plan and the Updated Nationally Determined Contribution of Ukraine to the Paris Agreement, we analyzed the structure of the installed capacities, annual electricity generation, storage, transmission, and trade with neighboring countries and calculated sustainability impacts (greenhouse gas and air pollution emissions, employment, land use, and total system costs). We showed that in 2035, the undamaged total installed capacity (as of May 2024) should be increased by 2.7–3.2 times while supplying up to 16.3 % higher electricity demand compared to the pre-war period. Nuclear and gas power would still remain the primary electricity sources in 2035, supported by intensive growth in wind power, pumped hydropower storage, bioenergy and expansion of transmission grids. Implementing environmentally friendly scenarios with 30 % of renewable generation and/or no hard coal power would require only 5 to 13 % higher total system costs compared to the least cost scenario, which could be socially and politically acceptable.
{"title":"Decarbonizing Ukraine's electricity sector in 2035: Scenario analysis","authors":"Iryna Sotnyk , Jan-Philipp Sasse , Evelina Trutnevyte","doi":"10.1016/j.egycc.2024.100170","DOIUrl":"10.1016/j.egycc.2024.100170","url":null,"abstract":"<div><div>In this study, we considered the case of decarbonizing Ukraine's electricity sector that has significant import dependence, high energy and carbon intensity, and an unprecedented destruction of electricity facilities due to ongoing war. Using a newly built UKRAINE-EXPANSE model, which covers 24 Ukrainian oblasts (regions) and five neighboring countries at high temporal and spatial resolution, we offered four cost-optimal scenarios for the national electricity sector in 2035. Considering the targets of the current National Energy and Climate Plan and the Updated Nationally Determined Contribution of Ukraine to the Paris Agreement, we analyzed the structure of the installed capacities, annual electricity generation, storage, transmission, and trade with neighboring countries and calculated sustainability impacts (greenhouse gas and air pollution emissions, employment, land use, and total system costs). We showed that in 2035, the undamaged total installed capacity (as of May 2024) should be increased by 2.7–3.2 times while supplying up to 16.3 % higher electricity demand compared to the pre-war period. Nuclear and gas power would still remain the primary electricity sources in 2035, supported by intensive growth in wind power, pumped hydropower storage, bioenergy and expansion of transmission grids. Implementing environmentally friendly scenarios with 30 % of renewable generation and/or no hard coal power would require only 5 to 13 % higher total system costs compared to the least cost scenario, which could be socially and politically acceptable.</div></div>","PeriodicalId":72914,"journal":{"name":"Energy and climate change","volume":"6 ","pages":"Article 100170"},"PeriodicalIF":5.8,"publicationDate":"2024-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143137662","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"Corrigendum to “Land use trade-offs in decarbonization of electricity generation in the American West” [Energy and Climate Change 4 (2023) 100107]","authors":"Neha Patankar , Xiili Sarkela-Basset , Greg Schivley , Emily Leslie , Jesse Jenkins","doi":"10.1016/j.egycc.2024.100130","DOIUrl":"10.1016/j.egycc.2024.100130","url":null,"abstract":"","PeriodicalId":72914,"journal":{"name":"Energy and climate change","volume":"5 ","pages":"Article 100130"},"PeriodicalIF":5.8,"publicationDate":"2024-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140271430","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-11-20DOI: 10.1016/j.egycc.2024.100169
Akwasi Adu-Poku , Ebenezer K. Siabi , Nathaniel Oppong Otchere , Francis B. Effah , Edward A. Awafo , Francis Kemausuor , Mashael Yazdanie
Hydropower is a major electricity source for Ghana, supplying about 28 % of the national generation capacity. Looking to the future, Ghana's vulnerability to drought may intensify with climate change projections in the Volta Basin indicating higher temperatures, more frequent extreme weather events and greater rainfall variability, which could exacerbate drought risks, alter river flow and disrupt electricity production from dams. This poses major energy security concerns for Ghana, which depends heavily on hydropower and has limited capacity to adapt. Therefore, this study evaluated the potential impacts of future droughts, measured by the Standardized Precipitation Evapotranspiration Index (SPEI), on hydropower generation and electricity pricing in Ghana under different Shared Socioeconomic Pathway (SSP) scenarios. A statistically significant Random Forest Regression model driven by SPEI projections was developed to forecast hydropower output from Ghana's largest hydropower plant, the Akosombo Dam, through 2050. Results indicate drought risks across SSPs, with more frequent hydropower generation deficits compared to optimal historical baseline averages. As generation fluctuates, electricity prices are forecast to continue rising substantially, although favourable socioeconomic pathways like SSP1 can limit price spikes. The findings underscore the importance of diversifying Ghana's electricity mix and implementing climate adaptation measures to hedge against increasing uncertainty in hydropower resources. The insights provide vital information to guide power sector planning and policies to build climate resilience.
{"title":"Impact of drought on hydropower generation in the Volta River basin and future projections under different climate and development pathways","authors":"Akwasi Adu-Poku , Ebenezer K. Siabi , Nathaniel Oppong Otchere , Francis B. Effah , Edward A. Awafo , Francis Kemausuor , Mashael Yazdanie","doi":"10.1016/j.egycc.2024.100169","DOIUrl":"10.1016/j.egycc.2024.100169","url":null,"abstract":"<div><div>Hydropower is a major electricity source for Ghana, supplying about 28 % of the national generation capacity. Looking to the future, Ghana's vulnerability to drought may intensify with climate change projections in the Volta Basin indicating higher temperatures, more frequent extreme weather events and greater rainfall variability, which could exacerbate drought risks, alter river flow and disrupt electricity production from dams. This poses major energy security concerns for Ghana, which depends heavily on hydropower and has limited capacity to adapt. Therefore, this study evaluated the potential impacts of future droughts, measured by the Standardized Precipitation Evapotranspiration Index (SPEI), on hydropower generation and electricity pricing in Ghana under different Shared Socioeconomic Pathway (SSP) scenarios. A statistically significant Random Forest Regression model driven by SPEI projections was developed to forecast hydropower output from Ghana's largest hydropower plant, the Akosombo Dam, through 2050. Results indicate drought risks across SSPs, with more frequent hydropower generation deficits compared to optimal historical baseline averages. As generation fluctuates, electricity prices are forecast to continue rising substantially, although favourable socioeconomic pathways like SSP1 can limit price spikes. The findings underscore the importance of diversifying Ghana's electricity mix and implementing climate adaptation measures to hedge against increasing uncertainty in hydropower resources. The insights provide vital information to guide power sector planning and policies to build climate resilience.</div></div>","PeriodicalId":72914,"journal":{"name":"Energy and climate change","volume":"5 ","pages":"Article 100169"},"PeriodicalIF":5.8,"publicationDate":"2024-11-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142720544","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-11-10DOI: 10.1016/j.egycc.2024.100164
Darya Maksakova, Sergei Popov
One of the primary challenges to the advancement of hydrogen technologies is their high costs. The study explores the potential of implementing green certificates for hydrogen, drawing parallels with the use of green certificates for electricity. The paper proposes a novel modeling tool to quantify the effect of trade in green certificates for hydrogen on trade flows and supply costs. The model is based on linear programming and covers both physical hydrogen trade and trade in green certificates for hydrogen simultaneously. An illustrative example is used to demonstrate the applicability of the model. The main conclusion is that the existence of a green certificate market could substantially reduce costs within a hydrogen supply system by reshaping transportation routes, all while maintaining the same level of low-carbon hydrogen production. This cost reduction effect raises hydrogen competitiveness and stimulates its production in remote areas.
{"title":"Green certificates for optimizing low-carbon hydrogen supply chain","authors":"Darya Maksakova, Sergei Popov","doi":"10.1016/j.egycc.2024.100164","DOIUrl":"10.1016/j.egycc.2024.100164","url":null,"abstract":"<div><div>One of the primary challenges to the advancement of hydrogen technologies is their high costs. The study explores the potential of implementing green certificates for hydrogen, drawing parallels with the use of green certificates for electricity. The paper proposes a novel modeling tool to quantify the effect of trade in green certificates for hydrogen on trade flows and supply costs. The model is based on linear programming and covers both physical hydrogen trade and trade in green certificates for hydrogen simultaneously. An illustrative example is used to demonstrate the applicability of the model. The main conclusion is that the existence of a green certificate market could substantially reduce costs within a hydrogen supply system by reshaping transportation routes, all while maintaining the same level of low-carbon hydrogen production. This cost reduction effect raises hydrogen competitiveness and stimulates its production in remote areas.</div></div>","PeriodicalId":72914,"journal":{"name":"Energy and climate change","volume":"5 ","pages":"Article 100164"},"PeriodicalIF":5.8,"publicationDate":"2024-11-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142655621","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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