Pub Date : 2025-02-20DOI: 10.1016/j.jup.2025.101900
S. van Schendel , I.A.M. Varenhorst
{"title":"A time aggregation approach for reducing identifiability in household energy data","authors":"S. van Schendel , I.A.M. Varenhorst","doi":"10.1016/j.jup.2025.101900","DOIUrl":"10.1016/j.jup.2025.101900","url":null,"abstract":"","PeriodicalId":23554,"journal":{"name":"Utilities Policy","volume":"94 ","pages":"Article 101900"},"PeriodicalIF":3.8,"publicationDate":"2025-02-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143455009","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"经济学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-02-19DOI: 10.1016/j.jup.2025.101902
Yan Xu, Xinyu Zhang, Kai Wang
This paper considers the government, electric power enterprises, and digital service providers as the primary stakeholders in the digital transformation of the electric power sector and constructs a game model to explore paths and strategies in the evolutionary process. The results show that the synergistic income between electric power enterprises and digital service providers significantly impacts whether the enterprises undergo digital transformation. The intensity of government subsidies and the severity of penalties influence the willingness to participate in the digital transformation and directly impact cooperative relationships. Cost is the fundamental reason for restricting the digital transformation of electric power enterprises.
{"title":"Stakeholder interaction in the digital transformation of China's electric power sector: An evolutionary game model","authors":"Yan Xu, Xinyu Zhang, Kai Wang","doi":"10.1016/j.jup.2025.101902","DOIUrl":"10.1016/j.jup.2025.101902","url":null,"abstract":"<div><div>This paper considers the government, electric power enterprises, and digital service providers as the primary stakeholders in the digital transformation of the electric power sector and constructs a game model to explore paths and strategies in the evolutionary process. The results show that the synergistic income between electric power enterprises and digital service providers significantly impacts whether the enterprises undergo digital transformation. The intensity of government subsidies and the severity of penalties influence the willingness to participate in the digital transformation and directly impact cooperative relationships. Cost is the fundamental reason for restricting the digital transformation of electric power enterprises.</div></div>","PeriodicalId":23554,"journal":{"name":"Utilities Policy","volume":"94 ","pages":"Article 101902"},"PeriodicalIF":3.8,"publicationDate":"2025-02-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143437806","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"经济学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-02-18DOI: 10.1016/j.jup.2025.101899
Franky BA Kogueda , Nassibou Bassongui , Marius Bendoma
This article assesses the impact of independent regulation on electricity supply, using data from 40 Sub-Saharan African countries over the period 2000 to 2021. Based on the propensity score matching method, we estimate the average effect of independent regulation. The results show that independent regulation positively impacts electricity generation, access to electricity, and service demand coverage. However, we find that independent regulatory authorities have no significant effect on electricity losses. A heterogeneity analysis by regional sub-blocks highlights that independent regulation enhances the allocative efficiency of electricity services in rural areas, particularly in countries experiencing social instability and insecurity. Conversely, independent regulatory authorities do not significantly affect the productive efficiency of electricity operators. These findings support the development of regulatory frameworks through the establishment of independent regulatory bodies, rural electrification initiatives, and competition authorities.
{"title":"Do independent regulatory authorities impact electricity supply in Sub-Saharan Africa?","authors":"Franky BA Kogueda , Nassibou Bassongui , Marius Bendoma","doi":"10.1016/j.jup.2025.101899","DOIUrl":"10.1016/j.jup.2025.101899","url":null,"abstract":"<div><div>This article assesses the impact of independent regulation on electricity supply, using data from 40 Sub-Saharan African countries over the period 2000 to 2021. Based on the propensity score matching method, we estimate the average effect of independent regulation. The results show that independent regulation positively impacts electricity generation, access to electricity, and service demand coverage. However, we find that independent regulatory authorities have no significant effect on electricity losses. A heterogeneity analysis by regional sub-blocks highlights that independent regulation enhances the allocative efficiency of electricity services in rural areas, particularly in countries experiencing social instability and insecurity. Conversely, independent regulatory authorities do not significantly affect the productive efficiency of electricity operators. These findings support the development of regulatory frameworks through the establishment of independent regulatory bodies, rural electrification initiatives, and competition authorities.</div></div>","PeriodicalId":23554,"journal":{"name":"Utilities Policy","volume":"94 ","pages":"Article 101899"},"PeriodicalIF":3.8,"publicationDate":"2025-02-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143437808","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"经济学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-02-13DOI: 10.1016/j.jup.2025.101895
Antonio Massarutto, Stefania Troiano
{"title":"Maintaining water service quality in the face of climate change: Can stated-preference analysis support priority setting?","authors":"Antonio Massarutto, Stefania Troiano","doi":"10.1016/j.jup.2025.101895","DOIUrl":"10.1016/j.jup.2025.101895","url":null,"abstract":"","PeriodicalId":23554,"journal":{"name":"Utilities Policy","volume":"93 ","pages":"Article 101895"},"PeriodicalIF":3.8,"publicationDate":"2025-02-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143402943","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"经济学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-02-01DOI: 10.1016/j.jup.2025.101892
Ricardo Messias , Pedro M.S. Carvalho , Jorge Sousa
Flexibility, defined as the ability to change load demand and generation injection over time, is touted as a key strategy to overcoming the challenges of increased net-load variability that come with higher penetration of variable renewable energy sources (VRES). Increased net-load variability places greater demands on the electrical grid, whose development pace is targeted as a bottleneck to achieving a decarbonized energy system. Policymakers and regulators want to mitigate the limitations in grid development by compelling distribution system operators (DSO) to consider the locally available distributed flexibility resources (DFR) as virtual capacity providers when planning the expansion of the distribution networks' physical assets. This analysis focuses on flexibility from the DSO perspective, trying to set an end-to-end epistemological common ground for policymakers, regulators and DSOs. It analyses the current public policy framework, setting the conventional planning objectives as a basis to understand the flexibility boundaries, and proposes an optimal capacity planning methodology where flexibility is taken as a new decision dimension, whose value can be obtained using a counterfactual approach, to be used in flexibility markets.
{"title":"Hybrid distribution network planning to incorporate virtual capacity from distributed flexibility resources","authors":"Ricardo Messias , Pedro M.S. Carvalho , Jorge Sousa","doi":"10.1016/j.jup.2025.101892","DOIUrl":"10.1016/j.jup.2025.101892","url":null,"abstract":"<div><div>Flexibility, defined as the ability to change load demand and generation injection over time, is touted as a key strategy to overcoming the challenges of increased net-load variability that come with higher penetration of variable renewable energy sources (VRES). Increased net-load variability places greater demands on the electrical grid, whose development pace is targeted as a bottleneck to achieving a decarbonized energy system. Policymakers and regulators want to mitigate the limitations in grid development by compelling distribution system operators (DSO) to consider the locally available distributed flexibility resources (DFR) as virtual capacity providers when planning the expansion of the distribution networks' physical assets. This analysis focuses on flexibility from the DSO perspective, trying to set an end-to-end epistemological common ground for policymakers, regulators and DSOs. It analyses the current public policy framework, setting the conventional planning objectives as a basis to understand the flexibility boundaries, and proposes an optimal capacity planning methodology where flexibility is taken as a new decision dimension, whose value can be obtained using a counterfactual approach, to be used in flexibility markets.</div></div>","PeriodicalId":23554,"journal":{"name":"Utilities Policy","volume":"93 ","pages":"Article 101892"},"PeriodicalIF":3.8,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143099105","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"经济学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-02-01DOI: 10.1016/j.jup.2024.101839
Ditao Duan , Roza Poursoleiman
{"title":"Retraction notice to Modified teaching-learning-based optimization by orthogonal learning for optimal design of an electric vehicle charging station [Utilities Policy 72 (2021) 101253]","authors":"Ditao Duan , Roza Poursoleiman","doi":"10.1016/j.jup.2024.101839","DOIUrl":"10.1016/j.jup.2024.101839","url":null,"abstract":"","PeriodicalId":23554,"journal":{"name":"Utilities Policy","volume":"92 ","pages":"Article 101839"},"PeriodicalIF":3.8,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143158127","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"经济学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-02-01DOI: 10.1016/j.jup.2025.101893
Tensay Hadush Meles , Alemu Mekonnen , Marc Jeuland , Abebe D. Beyene , Thomas Klug , Sied Hassen , Samuel Sebsibie , Subhrendu K. Pattanayak
Frequent and prolonged power outages severely impede business operations in many developing countries. Given resource constraints, estimating the value of improved electricity reliability in such contexts is crucial for justifying related investments. This analysis uses a split-sample design to examine whether business enterprises in Addis Ababa, Ethiopia, have different valuations for improved power supply reliability under two payment vehicles (electricity bill increases and tax revenue allocation). Results show that these businesses are willing to pay (WTP) an average of US$33 per year for a 1-h monthly reduction in outages and US$24 per year for one less outage per month. These amounts represent approximately 11% and 8% of the typical annual electricity bill of 10,615 Birr (US$295), respectively, highlighting that businesses place substantial value on electricity reliability. We find no significant differences in preferences or WTP estimates between the bill and tax payment vehicle sub-samples, suggesting that tax payment vehicles are as credible as bill increases in stated preference studies and that multiple mechanisms for financing power reliability investments may be feasible in practice.
{"title":"Does the payment vehicle matter for valuing improved electricity reliability? A discrete choice experiment in Ethiopia","authors":"Tensay Hadush Meles , Alemu Mekonnen , Marc Jeuland , Abebe D. Beyene , Thomas Klug , Sied Hassen , Samuel Sebsibie , Subhrendu K. Pattanayak","doi":"10.1016/j.jup.2025.101893","DOIUrl":"10.1016/j.jup.2025.101893","url":null,"abstract":"<div><div>Frequent and prolonged power outages severely impede business operations in many developing countries. Given resource constraints, estimating the value of improved electricity reliability in such contexts is crucial for justifying related investments. This analysis uses a split-sample design to examine whether business enterprises in Addis Ababa, Ethiopia, have different valuations for improved power supply reliability under two payment vehicles (electricity bill increases and tax revenue allocation). Results show that these businesses are willing to pay (WTP) an average of US$33 per year for a 1-h monthly reduction in outages and US$24 per year for one less outage per month. These amounts represent approximately 11% and 8% of the typical annual electricity bill of 10,615 Birr (US$295), respectively, highlighting that businesses place substantial value on electricity reliability. We find no significant differences in preferences or WTP estimates between the bill and tax payment vehicle sub-samples, suggesting that tax payment vehicles are as credible as bill increases in stated preference studies and that multiple mechanisms for financing power reliability investments may be feasible in practice.</div></div>","PeriodicalId":23554,"journal":{"name":"Utilities Policy","volume":"93 ","pages":"Article 101893"},"PeriodicalIF":3.8,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143099106","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"经济学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
This study assesses the economic and technical performance of four energy policy scenarios for Jordan's residential photovoltaic (PV) systems: net metering, net billing, zero-export with battery storage, and sell-all-buy-all. With the recent introduction of time-of-use (TOU) tariffs and policies addressing the “duck curve” effect, the research focuses on optimizing PV system sizing across different regulatory frameworks. A detailed techno-economic analysis evaluates these scenarios based on energy production, cost savings, payback periods, and energy self-sufficiency. The findings indicate that net metering and net billing offer the highest cost savings and the shortest payback periods (∼3 years). While the zero-export strategy with battery storage enhances energy self-sufficiency by up to 70%, it requires a higher upfront investment. The sell-all-buy-all scenario supports larger system sizes, achieving a low levelized cost of electricity (0.0696 USD/kWh) and a net present value of 619 USD. Additionally, the study identifies a critical feed-in tariff threshold of 0.055 USD/kWh, at which net billing becomes as financially attractive as net metering. These insights offer valuable recommendations for policymakers to optimize net billing rates and TOU tariffs, promoting the expansion of Jordan's renewable energy sector.
{"title":"Techno-economic assessment of residential PV system tariff policies in Jordan","authors":"Mohammad Alrbai , Loiy Al-Ghussain , Sameer Al-Dahidi , Osama Ayadi , Sahban Al-naser","doi":"10.1016/j.jup.2025.101894","DOIUrl":"10.1016/j.jup.2025.101894","url":null,"abstract":"<div><div>This study assesses the economic and technical performance of four energy policy scenarios for Jordan's residential photovoltaic (PV) systems: net metering, net billing, zero-export with battery storage, and sell-all-buy-all. With the recent introduction of time-of-use (TOU) tariffs and policies addressing the “duck curve” effect, the research focuses on optimizing PV system sizing across different regulatory frameworks. A detailed techno-economic analysis evaluates these scenarios based on energy production, cost savings, payback periods, and energy self-sufficiency. The findings indicate that net metering and net billing offer the highest cost savings and the shortest payback periods (∼3 years). While the zero-export strategy with battery storage enhances energy self-sufficiency by up to 70%, it requires a higher upfront investment. The sell-all-buy-all scenario supports larger system sizes, achieving a low levelized cost of electricity (0.0696 USD/kWh) and a net present value of 619 USD. Additionally, the study identifies a critical feed-in tariff threshold of 0.055 USD/kWh, at which net billing becomes as financially attractive as net metering. These insights offer valuable recommendations for policymakers to optimize net billing rates and TOU tariffs, promoting the expansion of Jordan's renewable energy sector.</div></div>","PeriodicalId":23554,"journal":{"name":"Utilities Policy","volume":"93 ","pages":"Article 101894"},"PeriodicalIF":3.8,"publicationDate":"2025-01-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143099104","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"经济学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-01-22DOI: 10.1016/j.jup.2025.101889
Charalampos Ziras , Jan Martin Zepter , Shahatphong Pechrak , Georgios Tsaousoglou
The proliferation of flexible resources in the electric distribution network and their active management have already started to cause congestion problems, mainly in areas with significant electric vehicle penetration. In this work, we study the reduction of usable capacity as a congestion management measure in a local flexibility market context. Using an extensive two-year residential charging dataset from Denmark, we highlight the problems caused by the almost 50% non-utilized capacity on an aggregated level of household chargers. We discuss and address various market design challenges and the implications of free excess capacity by treating aggregated capacity as a divisible good that can be traded between a distribution system operator (DSO) and flexibility service providers. The use of capacity blocks streamlines service delivery and overcomes many of the challenges of using explicit services. Finally, we show empirically that a simple, uniform pricing, two-stage auction significantly reduces DSO payments and mitigates the issue of excessive profit margins compared to a single-stage auction.
{"title":"Designing a local flexibility market for buying back capacity from electricity consumers connected to the distribution network","authors":"Charalampos Ziras , Jan Martin Zepter , Shahatphong Pechrak , Georgios Tsaousoglou","doi":"10.1016/j.jup.2025.101889","DOIUrl":"10.1016/j.jup.2025.101889","url":null,"abstract":"<div><div>The proliferation of flexible resources in the electric distribution network and their active management have already started to cause congestion problems, mainly in areas with significant electric vehicle penetration. In this work, we study the reduction of usable capacity as a congestion management measure in a local flexibility market context. Using an extensive two-year residential charging dataset from Denmark, we highlight the problems caused by the almost 50% non-utilized capacity on an aggregated level of household chargers. We discuss and address various market design challenges and the implications of free excess capacity by treating aggregated capacity as a divisible good that can be traded between a distribution system operator (DSO) and flexibility service providers. The use of <em>capacity blocks</em> streamlines service delivery and overcomes many of the challenges of using explicit services. Finally, we show empirically that a simple, uniform pricing, two-stage auction significantly reduces DSO payments and mitigates the issue of excessive profit margins compared to a single-stage auction.</div></div>","PeriodicalId":23554,"journal":{"name":"Utilities Policy","volume":"93 ","pages":"Article 101889"},"PeriodicalIF":3.8,"publicationDate":"2025-01-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143099103","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"经济学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-01-21DOI: 10.1016/j.jup.2025.101887
Ana Paula Barreira , Gonçalo Jacinto
Portugal faces water scarcity challenges, yet studies on per-household water consumption are limited. This study aims to address this gap by employing cluster analyses to assess how population trajectories, a previously overlooked aspect, and the regional location influence per-household monthly water consumption across 122 municipalities. Findings highlight higher consumption in the South despite lower prices. Municipalities experiencing population growth and those with long-term population declines show higher per-household water consumption but lower prices. Interestingly, while higher prices correlate with lower consumption, southern municipalities show increased prices without reduced consumption. Clustering reveals slight changes in consumption patterns from 2011 to 2020.
{"title":"Clustered patterns of household water consumption in Portuguese municipalities: Do regional location and population trajectory matter?","authors":"Ana Paula Barreira , Gonçalo Jacinto","doi":"10.1016/j.jup.2025.101887","DOIUrl":"10.1016/j.jup.2025.101887","url":null,"abstract":"<div><div>Portugal faces water scarcity challenges, yet studies on per-household water consumption are limited. This study aims to address this gap by employing cluster analyses to assess how population trajectories, a previously overlooked aspect, and the regional location influence per-household monthly water consumption across 122 municipalities. Findings highlight higher consumption in the South despite lower prices. Municipalities experiencing population growth and those with long-term population declines show higher per-household water consumption but lower prices. Interestingly, while higher prices correlate with lower consumption, southern municipalities show increased prices without reduced consumption. Clustering reveals slight changes in consumption patterns from 2011 to 2020.</div></div>","PeriodicalId":23554,"journal":{"name":"Utilities Policy","volume":"93 ","pages":"Article 101887"},"PeriodicalIF":3.8,"publicationDate":"2025-01-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143099102","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"经济学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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