Electricity Journal最新文献

{"title":"Powering agricultural revival: How solar-based irrigation is transforming Northeast Syria's war-torn fields","authors":"Elkhan Richard Sadik-Zada ,&nbsp;Sultan Jalabi","doi":"10.1016/j.tej.2025.107471","DOIUrl":"10.1016/j.tej.2025.107471","url":null,"abstract":"<div><div>This study examines the impact of solar-powered irrigation on agricultural recovery in the Abadan sub-district of northeast Syria, a region severely affected by war and drought. The research evaluates five dimensions of agricultural recovery: profitability, productivity, job creation effects, investment attraction, and household expenditures. The analysis, conducted using propensity score matching, indicates that solar-powered irrigation significantly enhances agricultural profitability, with solar users earning an average of $20.42 more per acre compared to diesel users (p = 0.001). Wheat productivity showed a modest increase from 0.151 to 0.179 tons per acre, though the difference was statistically insignificant (p = 0.365). Similarly, solar-based farms generated an average of 87.42 working days per year, compared to 75.30 days for diesel-based farms, but this difference was also not statistically significant (p = 0.60). Despite these mixed outcomes, the study highlights a significant shift towards the cultivation of summer crops, such as cotton, facilitated by more reliable water supply provided by solar-powered irrigation. These findings emphasize the importance of targeted interventions, including the promotion of advanced irrigation techniques and financial support for infrastructure development. Such measures are critical for maximizing the benefits of solar-based irrigation and ensuring broader, more sustainable agricultural recovery in the region.</div></div>","PeriodicalId":35642,"journal":{"name":"Electricity Journal","volume":"38 2","pages":"Article 107471"},"PeriodicalIF":0.0,"publicationDate":"2025-04-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143855971","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}

{"title":"Increasing the resilience of electricity networks: Auctioning of priority supply to minimize outage costs","authors":"Anna Pechan,&nbsp;Gert Brunekreeft,&nbsp;Martin Palovic","doi":"10.1016/j.tej.2025.107470","DOIUrl":"10.1016/j.tej.2025.107470","url":null,"abstract":"<div><div>This article presents an approach to minimize outage costs during power supply disruptions and, thus, to incentivize efficient resilience investment by network users. It serves as an initial contribution to creating incentives for greater resilience in the energy system. The central problem to be solved is the information asymmetry between network operators and network users in terms of outage and backup costs. We present an auction of priority positions among network users by applying the Vickrey-Clarke-Groves mechanism, using a numerical example, to solve this problem. Priority positions imply an externality: the priority of one user means that others are reconnected later and incur higher costs. Under this mechanism, each winning bidder pays for the externality exerted on the other bidders by holding a certain position, excluding one’s own bid, which induces truthful bidding. By minimizing the damage from power supply interruptions, the mechanism improves the resilience of the power system not only in the short term but also in the long term.</div></div>","PeriodicalId":35642,"journal":{"name":"Electricity Journal","volume":"38 2","pages":"Article 107470"},"PeriodicalIF":0.0,"publicationDate":"2025-04-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143817167","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}

{"title":"Electrification of the joint force: Challenges and opportunities for competition in the Pacific and Arctic theaters","authors":"Joshua D. Simulcik ,&nbsp;Fabian E. Villalobos ,&nbsp;Morgan D. Bazilian","doi":"10.1016/j.tej.2025.107458","DOIUrl":"10.1016/j.tej.2025.107458","url":null,"abstract":"<div><div>Operational energy is, and will continue to be, critical to success in the Department of Defense’s priority operating environments. The DoD is facing several challenges that call for the joint force to transform its concepts of operational energy including growing demand for energy services on the battlefield stemming from larger quantities of more capable equipment, large theaters with long and complex supply lines, and dispersed operational concepts. To meet these challenges, the DoD will have to find ways to expand the portfolio of its energy sources, continue to refine its supply chains and delivery mechanisms for energy services, improve efficiency across systems, and maintain a focus on costs. This paper will focus on the electrification of aspects of operational energy within the joint force as a means of increasing the effectiveness and efficiency of energy at all levels of warfighting. Of most relevance to electrification are technologies related to the military functions of logistics, transportation, weapons, and communications. We consider the various options, challenges, and opportunities of electrification for the US military.</div></div>","PeriodicalId":35642,"journal":{"name":"Electricity Journal","volume":"38 1","pages":"Article 107458"},"PeriodicalIF":0.0,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143150171","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":"How income and price changes affect the electricity demand? Evidence from Türkiye’s residential sector","authors":"İsmail Kavaz","doi":"10.1016/j.tej.2025.107459","DOIUrl":"10.1016/j.tej.2025.107459","url":null,"abstract":"<div><div>This study undertakes a comprehensive analysis of the income and price elasticities of residential electricity demand for Türkiye, spanning from 1980 to 2018. By employing the Structural Time Series Modelling method, the short- and long-run factors of income elasticities are found as 0.20 and 0.32, while the corresponding price parameters are determined as −0.08 for the short-term and −0.14 in the long-term, respectively. These elasticity estimations are crucial for informing policy-making processes, particularly in strategizing for the residential sector in Türkiye. The inelastic nature of these estimates, being less than 1, suggests that electricity constitutes a necessary commodity within the residential sector of Türkiye. It implies a limited sensitivity of consumers to fluctuations in price and income, indicating that changes in these factors do not significantly alter residential electricity demand in Türkiye. Additionally, this study extends its insights by providing forecasts for residential electricity demand. The projections indicate that by the year 2030, the electricity demand within Türkiye’s residential sector is projected to range between 90 and 106 Terawatt-hours (TWh). This forecasted data serves as an essential tool for future planning and policy development in the context of residential electricity consumption.</div></div>","PeriodicalId":35642,"journal":{"name":"Electricity Journal","volume":"38 1","pages":"Article 107459"},"PeriodicalIF":0.0,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143150172","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}

{"title":"Assessing the impact of rural electrification on gender inequality in rural India: A state-level analysis","authors":"Tanaya Saha","doi":"10.1016/j.tej.2025.107460","DOIUrl":"10.1016/j.tej.2025.107460","url":null,"abstract":"<div><div>Electricity has an unswerving impact on financial sustainability of a country; hence, everybody must have equal access to electricity. However, in a developing country like India, the inequality in electricity distribution intensifies in the rural areas and gets further skewed with respect to gender. The skewness is owing to the differential gender needs. The study has attempted to empirically analyze the impact of rural electrification on gender inequality across rural areas of 36 Indian states and union territories over 2015–2019. Gender inequality is measured through the ratio of female and male rural labor force participation, while rural literacy gap and self-help group loans are taken as controls. The analysis is carried out at the aggregate level, followed by segregation based on presence or absence of women police stations, geographical regions, and quantiles. The results show that although rural electrification and other drivers of gender inequality can have positive impact on achieving rural gender equality in rural India, there is need of policies that can help in maximizing use of electrification.</div></div>","PeriodicalId":35642,"journal":{"name":"Electricity Journal","volume":"38 1","pages":"Article 107460"},"PeriodicalIF":0.0,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143436893","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}

{"title":"Practical energy equity decision making in resource-constrained communities: A case study in the Navajo Nation","authors":"Abhiroop Chattopadhyay ,&nbsp;Ann-Perry Witmer","doi":"10.1016/j.tej.2025.107456","DOIUrl":"10.1016/j.tej.2025.107456","url":null,"abstract":"<div><div>There is an increasing recognition of the central role of energy equity and social justice in energy planning. Governments, utilities, planners, and the research community are working to advance a more nuanced understanding of energy equity, involving distributive, procedural, recognitional, and restorative aspects. Complete energy equity requires a holistic understanding of all these aspects, and energy planning should attempt to address them simultaneously. In practice, this can be challenging in contexts where the available pool of human and economic resources is limited. This article presents a case study of a community within the Navajo Nation to illustrate the challenges and implications in such contexts. The first challenge is the inevitable prioritization and compartmentalization of decision making due to the constraints imposed by the planners’ primary mandates, authority, place-based contextual factors, and available resources. The second – related – challenge is the impact of the resulting decisions on realized outcomes, and its effects on the community perceptions of – and confidence in – the planning institutions. The case study also finds that equity concerns of the utility’s end-customers may not always be uniform and are influenced by the customers’ perspectives, roles, responsibilities, and expectations. Thus, a more holistic view of energy planning is necessary to 1) capture the variations of equity opinions and priorities across all stakeholders, 2) to ensure that decisions and resource allocations by utilities, elected bodies, or governmental agencies occur on multiple fronts in a coordinated and transparent manner to advance energy equity targets.</div></div>","PeriodicalId":35642,"journal":{"name":"Electricity Journal","volume":"38 1","pages":"Article 107456"},"PeriodicalIF":0.0,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143151178","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}

{"title":"Short-term load forecasting with deep learning: Improving performance with post-training specialization","authors":"Igor Westphal","doi":"10.1016/j.tej.2024.107449","DOIUrl":"10.1016/j.tej.2024.107449","url":null,"abstract":"<div><div>Load forecasting has increasingly relied on deep learning models due to their ability to capture complex non-linear relationships. However, these models require substantial amounts of data for effective training. Data sparsity during peak load periods can degrade the performance of deep learning models to the point that they under-perform much simpler models. To address this issue, this paper proposes a post-training specialization method in which several copies of the original deep learning model are retrained for specific forecasting tasks. Results indicate an increase in performance in all baseline models used in this paper, and the method can potentially improve the forecasting of current applications at a low computational cost.</div></div>","PeriodicalId":35642,"journal":{"name":"Electricity Journal","volume":"38 1","pages":"Article 107449"},"PeriodicalIF":0.0,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143150170","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}

{"title":"Aligning electric vehicle charging with the sun: An opportunity for daytime charging?","authors":"Farzan ZareAfifi,&nbsp;Ricardo de Castro,&nbsp;Sarah Kurtz","doi":"10.1016/j.tej.2025.107457","DOIUrl":"10.1016/j.tej.2025.107457","url":null,"abstract":"<div><div>Recent studies show how a strategic shift towards daytime charging of electric vehicles (EVs) has the potential to be a powerful game-changer, leveraging flexible EV loads to maintain solar value on the grid and aligning EV charging energy load with solar generation. Also, recent studies show the benefits of expanding investment in daytime charging infrastructure and reforming time-of-use rates to promote daytime charging. By harmonizing energy consumption patterns with solar supply, we can increase the solar industry's economic appeal and sustain its growth trajectory while potentially reducing cost and improving convenience for charging vehicles that are parked during the day. This study integrates all these different studies and provides a comprehensive perspective on the benefits, challenges, and barriers to implementing daytime EV charging at scale.</div></div>","PeriodicalId":35642,"journal":{"name":"Electricity Journal","volume":"38 1","pages":"Article 107457"},"PeriodicalIF":0.0,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143151177","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":"Energy storage as a transmission asset: Definitions and use cases","authors":"Jeremy Twitchell","doi":"10.1016/j.tej.2024.107441","DOIUrl":"10.1016/j.tej.2024.107441","url":null,"abstract":"<div><div>There is growing interest in deploying energy storage as a transmission asset (SATA), as evidenced by an evolving body of supportive policies and regulations and an expanding body of literature on the topic. Despite nearly two decades of evolution, however, transmission planning processes in the United States rarely consider storage alternatives and only a handful of projects have been selected. Regulators have assigned the responsibility of proposing non-transmission alternatives to non-utility participants in the planning process, so the sparse record of SATA projects may therefore result from a lack of specificity about the use cases for SATA and uncertainty about when it should be proposed. Extensive literature has been devoted to the topic of SATA, but much of it relies on definitions that are inconsistent with regulatory precedent and that exacerbate confusion. This paper reviews regulatory proceedings to define three types of energy storage assets than can interact with the transmission system: storage <u>as</u> a transmission asset, storage <u>in place of</u> a transmission asset (SIPTA), and <u>dual-use</u> energy storage. It then provides an inventory of use cases for SATA and SIPTA projects, using brief case studies to illustrate each use case. By clarifying the definition of SATA and its roles in transmission system planning, this work may be of use to transmission system planners and other participants in transmission planning processes to identify situations in which SATA alternatives merit consideration.</div></div>","PeriodicalId":35642,"journal":{"name":"Electricity Journal","volume":"37 7","pages":"Article 107441"},"PeriodicalIF":0.0,"publicationDate":"2024-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142552867","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}

{"title":"What FERC should do to enable interregional electric transmission","authors":"Robert H. Schulte,&nbsp;Raymond J. Wahle","doi":"10.1016/j.tej.2024.107446","DOIUrl":"10.1016/j.tej.2024.107446","url":null,"abstract":"<div><div>The Federal Energy Regulatory Commission (FERC) on May 13, 2024 issued its Order 1920: “Building for the Future Through Electric Regional Transmission Planning and Cost Allocation”. Years in the making and building on its previous Order 1000 and others, this 1363-page Order is being hailed as a landmark in promoting needed electric transmission development in the United States going forward. While establishing needed detailed requirements for transmission planning <em>within</em> regions, the Order stopped short of addressing <em>interregional</em> planning other than identifying issues related to it.</div><div>Expanding on the traditional concept of <em>intra</em>regional transmission planning, <em>inter</em>regional planning offers advanced benefits including reduced production (fuel) costs, improved generation capacity sharing, increased clean energy supplies, reduced renewables curtailment, and improved reliability and resiliency by providing transmission support between regions.</div><div>On a parallel path, Congress has recently become very active in efforts related to encouraging interregional transmission. Multiple bills have been introduced the past two years, addressing permitting reform, requirements for interregional planning, specification of minimum interregional transfer capacity, and offering investment tax credits, among other topics. While Order 1920 is now subject to numerous appeals and lawsuits that will take time to be resolved, and the Congressional bills remain to be potentially combined and passed, these are all positive signs for interregional transmission development going forward.</div><div>Meanwhile, the authors have been engaged the past several years in working with multiple utilities toward development of the Power from the Prairie (PftP) interregional transmission project (www.powerfromtheprairie.com). While these utilities whom the authors recruited are a select few who can think outside their service territories toward potential interregional collaboration, significant challenges and obstacles still exist. These represent the real-world issues of whether interregional transmission can actually occur.</div><div>This article combines the content of FERC Order 1920 and the various Congressional bills with the on-the-ground experience with utilities thinking about doing interregional transmission. The authors conclude that there is much more FERC can and should do going beyond Order 1920, in concert with Congress and others, to enable interregional transmission development to happen. A “Road Map” of potential next actions by FERC is suggested. In addition, the need to form a new entity that takes a more holistic interregional transmission planning view to overcome current industry inertia is also discussed.</div></div>","PeriodicalId":35642,"journal":{"name":"Electricity Journal","volume":"37 7","pages":"Article 107446"},"PeriodicalIF":0.0,"publicationDate":"2024-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142658421","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}