Renewable Energy Focus最新文献

{"title":"Multi-objective optimization of a biogas-fired gas turbine incorporated with closed Brayton and ejector power/cooling co-generation cycles","authors":"M. Zare,&nbsp;V. Zare,&nbsp;F. Talati","doi":"10.1016/j.ref.2024.100658","DOIUrl":"10.1016/j.ref.2024.100658","url":null,"abstract":"<div><div>Fossil fuels have long been the primary source of energy for human consumption. However, with increasing population growth and industrialization, electricity demand continues to rise, necessitating a sustainable and clean energy supply to mitigate environmental damage and support global development. This research proposes a gas turbine-based power plant that utilizes renewable biogas as its fuel source. To enhance the plant’s efficiency, the gas turbine is integrated with a closed Brayton cycle, complemented by compressor intake cooling. This cooling process is achieved through a combined power and ejector refrigeration unit, which recovers waste heat from the gas turbine. The energy, exergy, and economic performance of the proposed plant are thoroughly analyzed, with exergy efficiency and unit product cost serving as the objective functions for multi-criteria optimization. The results demonstrate that compressor intake cooling improves both thermodynamic and economic performance under all operating conditions. At the optimal design point, the system with intake cooling achieves an exergy efficiency of 39.38%, compared to 33.64% for the system without it. Additionally, while the system with intake cooling requires higher initial investment, it offers lower unit product costs, making it a more economically viable option.</div></div>","PeriodicalId":29780,"journal":{"name":"Renewable Energy Focus","volume":"52 ","pages":"Article 100658"},"PeriodicalIF":4.2,"publicationDate":"2024-11-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142744162","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":"PyPSA-BD: A customized model to explore decarbonized energy transition for developing country","authors":"Firuz Ahamed Nahid ,&nbsp;Joyashree Roy","doi":"10.1016/j.ref.2024.100655","DOIUrl":"10.1016/j.ref.2024.100655","url":null,"abstract":"<div><div>This article provides high-resolution, evidence-based insights towards power sector planning for a developing country. We consider the PyPSA-BD model as a cutting-edge contribution as it’s a fully customized adaptation of PyPSA-Earth for Bangladesh to identify challenges and opportunities for transitioning to a decarbonized power system through counterfactual validation of inputs from national official statistics with a spatial resolution of 30km x 30km and an hourly temporal resolution. Its open-source framework is helpful for future researchers and decision-makers in developing countries like Bangladesh to develop more scenarios to answer any policy-relevant questions as per national need. With 2019 as a reference year, scenarios for 2030, 2041, and 2050 align with national renewable energy integration and decarbonization targets revealing cost-effective generation expansions, diversification of installed capacity through renewable energy penetration, net employment generation, additional land and investment requirement. Model results show that the 2019 installed capacity of 18.94 GW will grow to 61.45 GW by 2030, 102.36 GW by 2041, and 281.52 GW by 2050. By 2050, a storage capacity of 28.5 GW will be required to maintain grid stability. This transition could create approximately 6.7 million jobs and reduce generation costs to 7.63 BDT/kWh by 2050, requiring 3690.85 sq.km of land. Achieving these outcomes will demand an annual investment of approximately 1.99% of Bangladesh’s 2023 GDP from 2025, underscoring the need for national and international finance mobilization. The results guide policymakers to develop sustainable energy transition strategies for Bangladesh that provide power supply security at both spatial and temporal scale.</div></div>","PeriodicalId":29780,"journal":{"name":"Renewable Energy Focus","volume":"52 ","pages":"Article 100655"},"PeriodicalIF":4.2,"publicationDate":"2024-11-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142757408","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":"Transition to a 100% renewable grid for a remote island: A case study of Tsushima Island, Japan","authors":"Alireza Tavana ,&nbsp;Tatchaphon Leelaprachakul ,&nbsp;Soo-Bin Kim ,&nbsp;Daisuke Tokuda","doi":"10.1016/j.ref.2024.100657","DOIUrl":"10.1016/j.ref.2024.100657","url":null,"abstract":"<div><div>Remote islands face unique challenges in achieving carbon neutrality. These islands typically depend on imported fossil fuels, operate independently of larger grids, and experience high electricity costs. Furthermore, limited access to reliable data complicates efforts to design effective energy solutions. Tsushima Island, Japan, exemplifies these challenges. Through a comprehensive analysis informed by a site visit, this study explores the island’s energy landscape and identifies viable renewable resources. Two transition scenarios are proposed to achieve a 100% renewable energy system, addressing key issues such as energy security and sustainability. The findings demonstrate that a complete renewable energy transition is possible, providing a replicable model for other remote islands worldwide.</div></div>","PeriodicalId":29780,"journal":{"name":"Renewable Energy Focus","volume":"52 ","pages":"Article 100657"},"PeriodicalIF":4.2,"publicationDate":"2024-11-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142744061","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":"Renewable hydrogen systems for a sustainable heavy-duty mobility: The Italian case","authors":"Daniele Daminelli,&nbsp;Luciano Masotti,&nbsp;Silvia Corigliano","doi":"10.1016/j.ref.2024.100656","DOIUrl":"10.1016/j.ref.2024.100656","url":null,"abstract":"<div><div>This study offers a detailed economic and technical assessment of renewable hydrogen production, storage, and utilisation for heavy-duty transport in Italy. To achieve the initial targets set by the national hydrogen strategy for 2030, the heavy-duty fleet will require 3.6 GW of variable renewables, 1 GW of electrolyzers. The findings reveal that the Levelized Cost of renewable hydrogen varies based on system configurations, the mix of variable renewables, and electricity market zones. Specifically, hydrogen cost ranges from 7.5 €/kgH2 for grid-connected plants in market zones with high renewable electricity share, to 18.6 €/kgH2 for hydrogen plants connected to solar photovoltaic in the Northern zone. The South of Italy, Sicily, and Sardinia are the most suitable and cost effective zones for hydrogen production. However, low local demand projection necessitate network infrastructure investments to enable zonal transfer and prevent congestion risks.</div></div>","PeriodicalId":29780,"journal":{"name":"Renewable Energy Focus","volume":"52 ","pages":"Article 100656"},"PeriodicalIF":4.2,"publicationDate":"2024-11-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142703911","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":"Optimal operation of a residential energy hub participating in electricity and heat markets","authors":"Mehdi Davoudi ,&nbsp;Moein Moeini-Aghtaie ,&nbsp;Mahdi Mehrtash","doi":"10.1016/j.ref.2024.100646","DOIUrl":"10.1016/j.ref.2024.100646","url":null,"abstract":"<div><div>The integration of electricity and heat networks provides significant benefits by enhancing system flexibility and improving overall energy efficiency. Energy hubs play an important role in these interconnected systems, facilitating the production, conversion, and storage of energy across different forms. Potential flexible loads that may exist in an energy hub can further optimize its resource utilization and operational stability. In this respect, this paper addresses the day-ahead energy management of a residential complex modeled as an energy hub, incorporating medium-scale generation and storage units, as well as must-run and flexible loads. We also consider energy hub operator’s energy transactions in power distribution system and district heating and aim to obtain the optimal bidding strategy of this profit-driven agent. The negotiations among the energy hub operator, distribution system operator, and district heat network operator are modeled as a single-leader multi-follower Stackelberg game. A Nash Equilibrium of this game can be obtained by modeling the interactions among players as a bi-level optimization problem. The lower-level problems account for multi-period optimal power flow, modeled as an exact AC optimal power flow, and multi-period optimal thermal flow. The upper-level problem models the energy management of the energy hub. Replacing the lower-level problems with their optimality conditions, the optimal bidding of the energy hub operator can be obtained by solving the resulted mixed-integer linear programming problem as a mathematical program with equilibrium constraints. Finally, we numerically evaluate the proposed framework in a case study for a large residential complex participating in a power distribution and a heat network.</div></div>","PeriodicalId":29780,"journal":{"name":"Renewable Energy Focus","volume":"51 ","pages":"Article 100646"},"PeriodicalIF":4.2,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142528950","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":"Fueling Costa Rica’s green hydrogen future: A financial roadmap for global leadership","authors":"Andrea Navarro Jiménez ,&nbsp;Huaili Zheng","doi":"10.1016/j.ref.2024.100651","DOIUrl":"10.1016/j.ref.2024.100651","url":null,"abstract":"<div><div>This study evaluates the <strong>financial viability and scalability</strong> of <strong>green hydrogen production</strong> in Costa Rica, focusing on solar and wind energy. The research analyzes seven key provinces using <strong>Global Horizontal Irradiance (GHI)</strong> and wind speed data to assess energy potential. <strong>Monte Carlo simulations</strong> were employed to calculate the <strong>Net Present Value (NPV)</strong>, hydrogen production costs, and economic sustainability over multiple project lifetimes. <strong>Guanacaste</strong>, with solar irradiance of <strong>5.49 kWh/m²/day</strong> and wind speeds of <strong>6.59 m/s</strong>, emerges as the most favorable region. The analysis reveals an <strong>NPV of $1,519.79 USD</strong> for onshore wind and <strong>$2,320.24 USD</strong> for offshore wind over 10 years. These values increase significantly for longer lifetimes, with <strong>25-year NPVs</strong> of <strong>$3,687.40 USD</strong> for onshore wind and <strong>$5,890.72 USD</strong> for offshore wind, and <strong>50-year NPVs</strong> reaching <strong>$7,456.21 USD</strong> and <strong>$11,560.38 USD</strong>, respectively. <strong>Hydrogen production costs</strong> are estimated at <strong>$49,696.75 USD</strong> from solar and <strong>$14,923.19 USD</strong> from wind energy. Despite its potential, <strong>high costs</strong> remain a challenge, requiring <strong>policy incentives</strong>, <strong>international cooperation</strong>, and <strong>green bonds</strong> to drive down costs and scale production. The study offers crucial insights for <strong>policymakers</strong>, <strong>investors</strong>, and <strong>researchers</strong> to support Costa Rica’s leadership in the global <strong>green hydrogen economy</strong>.</div></div>","PeriodicalId":29780,"journal":{"name":"Renewable Energy Focus","volume":"51 ","pages":"Article 100651"},"PeriodicalIF":4.2,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142658425","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":"Life cycle greenhouse gas emissions assessment: converting an early retirement coal-fired power plant to a biomass power plant","authors":"Irhan Febijanto ,&nbsp;Nadirah Nadirah ,&nbsp;Rosmeika ,&nbsp;Nugroho A.S ,&nbsp;Arli Guardi ,&nbsp;A.I. Yanuar ,&nbsp;H. Bahua ,&nbsp;R. Herdioso ,&nbsp;A.L.S.M. Sihombing ,&nbsp;I.M.A.D. Susila ,&nbsp;B. Rustianto ,&nbsp;I.Z. Kurniawati ,&nbsp;M. Soleh ,&nbsp;T. Sugeng","doi":"10.1016/j.ref.2024.100643","DOIUrl":"10.1016/j.ref.2024.100643","url":null,"abstract":"<div><div>Decommissioning aging coal-fired power plants (CFPPs) represents an effective strategy for reducing greenhouse gas (GHG) emissions, accelerating energy mix diversification, and achieving nationally determined contributions and net-zero emissions targets. However, dismantling the CFPP and building a renewable energy-based power plant with a capacity equal to a dismantled CFPP could burden state finances. Therefore, converting coal to 100% biomass fuel in the aging CFPP is one of the proposals that needs to be studied. This study conducted an environmental assessment concerning the Life Cycle Greenhouse Gas (LC GHG) emissions, encompassing raw material extraction and power plant operation. Five scenarios were analyzed. Two scenarios related to using sawdust and agroforestry residue for biomass fuel in the aging CFPP. The other three scenarios used biomass fuel from Calliandra wood harvested from tropical forests, production forests, and marginal land, which produced GHG emissions from Land Use Change (LUC). This study demonstrates that sawdust and agroforestry residue can reduce global warming impacts compared to coal. The LUC in higher carbon stock land will increase global warming impacts, while the LUC in lower carbon stock land will reduce global warming impacts. A decrease in the aging CFPP efficiency, when coal is converted to 100% biomass, will cause an increase in global warming impacts.</div></div>","PeriodicalId":29780,"journal":{"name":"Renewable Energy Focus","volume":"51 ","pages":"Article 100643"},"PeriodicalIF":4.2,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142423118","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":"A methodology for preliminary benefit evaluation of Distributed Generation to drive private investments","authors":"Diogo Gomes de Almeida ,&nbsp;Renan Silva Maciel ,&nbsp;Bruno Soares Moreira Cesar Borba","doi":"10.1016/j.ref.2024.100644","DOIUrl":"10.1016/j.ref.2024.100644","url":null,"abstract":"<div><div>Private investments in distributed generation (DG) are typically driven by the interests of private investor, often overlooking possible benefits for the distribution operator. This work presents a methodology that enables power distribution utilities to assess the potential for attracting investments in their networks, considering a regulatory framework where utilities could actively encourage private DG investors. The methodology involves calculating and integrating the benefits associated with investment deferral, losses reduction and reliability improvement into the energy price negotiated between the utility and the DG owner. The proposed approach was applied to an adapted test grid, considering real regulatory aspects related to technical losses and reliability. The results provide support for utilities to perform preliminary financial analyses to determine the appropriate incentives for private DG investors, identifying cases with competitive energy prices for generators. Key contributions of this methodology include a clear and reasonable metric for quantifying the capacity to attract investments based on standard utility data and the importance of incorporating regulatory aspects related to technical losses and reliability, that are often neglected in similar studies. Furthermore, the methodology not only promotes new opportunities for DG investors but also addresses challenges associated with network congestion.</div></div>","PeriodicalId":29780,"journal":{"name":"Renewable Energy Focus","volume":"51 ","pages":"Article 100644"},"PeriodicalIF":4.2,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142423119","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":"Demand side management programs in smart grid through cloud computing","authors":"Mostafa Azimi Nasab ,&nbsp;Mohsen Hatami ,&nbsp;Mohammad Zand ,&nbsp;Morteza Azimi Nasab ,&nbsp;Sanjeevikumar Padmanaban","doi":"10.1016/j.ref.2024.100639","DOIUrl":"10.1016/j.ref.2024.100639","url":null,"abstract":"<div><div>The development of power systems requires smart grids to facilitate real-time control and monitoring using bilateral communications across the power grid. With the implementation of a distributed structure, smart grids will be highly reliable, efficient, and secure, as well as affordable in terms of power management. With the expansion of the power grid at the level of distribution and the smarter equipment used by the shareholders, it is necessary to consider measures to balance production and consumption and to optimize the consumer pattern. One of these approaches is the use of demand-side management programs, in which the system operator seeks to optimize the coordination between production units, storage units, and consumption loads in a way that achieves maximum social welfare. This article attempts to present models for planning a demand-side management program that is presented in the presence of new cloud computing technologies. The model proposed is based on the use of storage units and will be able, in addition to covering uncertainty in renewable production, to customize energy reserves and computational capacity in a way that brings the lowest operating costs.</div></div>","PeriodicalId":29780,"journal":{"name":"Renewable Energy Focus","volume":"51 ","pages":"Article 100639"},"PeriodicalIF":4.2,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142423120","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":"Life cycle assessment of photovoltaic panels including transportation and two end-of-life scenarios: Shaping a sustainable future for renewable energy","authors":"Hernández-López Daniela-Abigail ,&nbsp;Marisela I. Vega-De-Lille ,&nbsp;Julio C. Sacramento-Rivero ,&nbsp;Carmen Ponce-Caballero ,&nbsp;Amina El-Mekaoui ,&nbsp;Freddy Navarro-Pineda","doi":"10.1016/j.ref.2024.100649","DOIUrl":"10.1016/j.ref.2024.100649","url":null,"abstract":"<div><div>This research study addresses the growing environmental concerns associated with solar photovoltaic (PV) systems which is a pivotal component of renewable energy transition. The primary objective is to advance the comprehension of the environmental sustainability of solar PV technology, with a specific focus on the context of Mexico. This study applies a life cycle assessment (LCA) framework, employing an up-to-date methodology (ReCiPe 2016) and database (Ecoinvent 3.8) for midpoint and endpoint indicators in this problem by considering a specific focus on end-of-life and transportation scenarios which have been absent in the current state-of-the-art research. An LCA approach bridges the gap between midpoint and end-point indicators, bringing transparency to the environmental impact assessment. This research entails a cradle-to-grave LCA of a 1 kW crystalline silicon solar panel over a 25-year lifespan while adapting to ISO 14044 standards for LCA and encompassing both midpoint and end-point indicators, specifically including end-of-life and transportation scenario. Furthermore, a sensitivity analysis is conducted to evaluate the variations in environmental indicators considering the life-cycle data. It is reported that recycling processes can cause a substantial mitigating effect on environmental impacts across multiple categories, leading to reductions of up to 89 % in mineral resource scarcity. Notably, the cell processing phase emerges as the most environmentally impactful stage, accounting for 37 % of the total impact. This high impact is predominantly attributed to silver usage and heightened electricity consumption. The sensitivity analysis revealed that various performance indicators exhibited differing degrees of sensitivity to uncertainty in the design variables, highlighting the importance of careful consideration, particularly in addressing the<!--> <!-->impact on the<!--> <!-->ecosystem, when aiming to reduce environmental impacts in the life cycle of silicon solar panels. Our results have also indicated that transportation significantly impacts resource protection, accounting for 15 % of the total impacts in this category, with lesser yet notable contributions to ecosystems and human health. The implications of this work suggest a need for stringent policies to fabricate complete solar photovoltaic modules in Mexico to reduce the environmental burden caused by transportation. Additionally, the insights from this study offer a gateway for the Mexican government to reform current energy transition policies by including multiple recycling scenarios for solar photovoltaic systems, ultimately leading to sustainable growth in this market.</div></div>","PeriodicalId":29780,"journal":{"name":"Renewable Energy Focus","volume":"51 ","pages":"Article 100649"},"PeriodicalIF":4.2,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142528873","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}