Sustainable Energy Grids & Networks最新文献

{"title":"A novel industrial load scheduling model to balance scheduling with virtual power plant regulation requirements","authors":"Sheng Xian Cao,&nbsp;Lin Yue,&nbsp;Gong Wang,&nbsp;Gui Chao Duan,&nbsp;Kun Li,&nbsp;Jun Li,&nbsp;Ying Zhe Kang,&nbsp;Hui Jing Sun","doi":"10.1016/j.segan.2025.102109","DOIUrl":"10.1016/j.segan.2025.102109","url":null,"abstract":"<div><div>Within virtual power plants (VPPs), large industrial loads function as key controllable loads (CL), and precise load quantification is pivotal to achieving efficient VPP operation. For industrial loads subject to heterogeneous scheduling problem (SP) constraints alongside uncertain renewable outputs, production scheduling and energy use decisions are strongly coupled, and demand response (DR) execution can conflict with pre-established production plans. There is an urgent need to establish a VPP-oriented unified constraint set and feasible region. However, the coordination challenges of production scheduling optimization, economic performance improvement, and flexible participation in VPP operation remain insufficiently addressed. Accordingly, this paper proposes an industrial load scheduling model for virtual power plants (ILS-VPP), an industrial load scheduling model that reconciles factory-level scheduling with VPP-level regulation requirements. First, to address the difficulty of VPP participation under flexible job shop scheduling problem (FJSSP) constraints, we embed FJSSP into the optimization framework and unify the feasible region with participation constraints. Second, to overcome the limited adaptability of DR responses, we design a co-optimization mechanism that integrates production scheduling with DR. Third, to balance economic benefits and completion deadlines under high uncertainty, we develop a three-stage robust optimization (RO) strategy grounded in multi-polyhedral uncertainty sets, chance-constrained programming, and the <span><math><mi>ϵ</mi></math></span>-constraint method. An improved football team training algorithm (FTTA) is employed to solve the model, enhancing convergence stability and solution-set quality. A case study over a 90-day operating horizon shows that the proposed model improves economic performance by 21.3 %, can supply 11,003 kWh of energy to the VPP, achieves a load flexibility index (LFI) of 79.8 %, and increases the load factor (LF) from 0.708 to 0.807.</div></div>","PeriodicalId":56142,"journal":{"name":"Sustainable Energy Grids & Networks","volume":"45 ","pages":"Article 102109"},"PeriodicalIF":5.6,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145925959","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Risk-based industrial load management with integrated distributed energy resources to enhance grid flexibility and market participation","authors":"Nasim Eslaminia ,&nbsp;Sina Ghaemi ,&nbsp;Amjad Anvari-Moghaddam","doi":"10.1016/j.segan.2025.102115","DOIUrl":"10.1016/j.segan.2025.102115","url":null,"abstract":"<div><div>Industrial loads, with their inherent flexibility and growing integration of energy storage systems (ESSs) and photovoltaic (PV) generation, present a significant opportunity to enhance grid stability through ancillary services (ASs) and unlock financial benefits. However, uncertainties in renewable generation and market prices can complicate decision-making, particularly for risk-averse industrial entities. To address these challenges, this study develops a risk-based, mixed-integer linear programming (MILP) optimization model for day-ahead scheduling. This model leverages flexible assets and incorporates the Conditional Value-at-Risk (CVaR) technique to evaluate how risk preferences impact participation in energy and AS markets. Moreover, the proposed model integrates a detailed characterization of industrial sub-loads, assesses load flexibility, and accounts for the combined effects of renewable energy sources (RESs) and ESSs. Four case studies are used to analyze the participation of industrial loads, PV, and ESS in AS markets, investigating the influence of risk preferences and AS participation strategies. The case studies demonstrate that engaging in AS markets yields financial gains regardless of risk preference. The results emphasize the critical role of flexible assets in enhancing system flexibility, promoting greater involvement in energy and AS markets, and improving grid support capabilities.</div></div>","PeriodicalId":56142,"journal":{"name":"Sustainable Energy Grids & Networks","volume":"45 ","pages":"Article 102115"},"PeriodicalIF":5.6,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145884020","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The overvoltage-driven blackout of the Iberian Peninsula on 28th April 2025","authors":"L. Rouco,&nbsp;F.M. Echavarren,&nbsp;E. Lobato","doi":"10.1016/j.segan.2026.102125","DOIUrl":"10.1016/j.segan.2026.102125","url":null,"abstract":"<div><div>The Iberian Peninsula blackout on 28th April 2025 occurred due to cascading disconnection of renewable generation with power factor control, triggered by overvoltage generation protections. This paper describes a conceptual model to explain the primary phenomenon that occurred, which we have called an overvoltage-driven blackout. While the phenomenon of voltage collapse, or more precisely undervoltage collapse, is widely discussed in the scientific literature, the phenomenon of an overvoltage-driven blackout is new. An illustrative 3-bus small-scale power system is provided to better understand the evolution of bus voltages in an overvoltage-driven blackout, identifying the critical factors that can lead a power system to a blackout caused by overvoltage. The conceptual model is applied to the state of the Iberian Peninsula electricity system at 12:30 on 28th April 2025, preceding the blackout. The paper will show how, with the loss of renewable generation, the growth of bus voltages exhibits the same pattern as the one identified in the 3-bus small-scale system. A new safety metric (margin to overvoltage-driven blackout) is defined and computed. The paper will demonstrate how the system operated with an insufficient safety margin, leading to an overvoltage-driven blackout, due to a lack of sufficient synchronous reactive power absorption capacity in the central and southern parts of Spain, as well as the low-loaded transmission grid in those regions.</div></div>","PeriodicalId":56142,"journal":{"name":"Sustainable Energy Grids & Networks","volume":"45 ","pages":"Article 102125"},"PeriodicalIF":5.6,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"146077423","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A multi-objective approach for integrated energy hub with waste incineration plants integrating carbon capture technology, and electric vehicle parking lots under uncertainties","authors":"Phan Thanh Vinh ,&nbsp;Truong Hoang Bao Huy ,&nbsp;Pham Van Phu ,&nbsp;Namchul Cho ,&nbsp;Daehee Kim","doi":"10.1016/j.segan.2026.102121","DOIUrl":"10.1016/j.segan.2026.102121","url":null,"abstract":"<div><div>The rapid growth of municipal solid waste (MSW) and the urgent need for carbon emissions reduction present major challenges in sustainable energy system design. Waste incineration plants (WIPs), a key component of waste-to-energy (WtE) systems, convert MSW into usable energy. However, they generate considerable carbon emissions during the combustion process. Addressing these issues, this paper explores the potential of WtE technologies coupled with carbon capture (CC) and electric vehicle infrastructure within an integrated energy hub (IEH). A multi-objective mixed-integer linear programming paradigm for an IEH model is proposed where WIP-CC collaboration, renewable energy sources, power conversion components, storage system and electric vehicle parking lots are fully utilized. The augmented <span><math><mi>ε</mi></math></span>-constraint approach is employed for effectively solving the multi-objective IEH problem. In the proposed model, three objective functions are investigated: operation cost, emission tax, and export index (EI). The proposed IEH achieves an operation cost of $13,370.25, emission tax of $128.89, and an EI of 0 in the deterministic case. When considering uncertainties, the hybrid stochastic-IGDT model is applied to choose an optimal plan based on the characteristics of the uncertain parameters. Both risk-averse and risk-seeking strategies are studied to evaluate the trade-offs between solution robustness and performance, enabling more informed decision-making under varying levels of uncertainty.</div></div>","PeriodicalId":56142,"journal":{"name":"Sustainable Energy Grids & Networks","volume":"45 ","pages":"Article 102121"},"PeriodicalIF":5.6,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"146077419","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Optimal dispatch and impact analysis of power–heat–gas integrated energy systems considering carbon pricing schemes","authors":"Seoeun Rho ,&nbsp;Hee Seung Moon ,&nbsp;Won Young Park ,&nbsp;Dongjun Won","doi":"10.1016/j.segan.2025.102079","DOIUrl":"10.1016/j.segan.2025.102079","url":null,"abstract":"<div><div>With the global shift toward carbon neutrality and the implementation of emissions trading systems, the interaction between emission allowance allocation scheme and the operation of sector-coupled integrated energy systems becomes increasingly important. This paper develops a linearized optimal dispatch strategy for an power–heat–gas integrated energy systems with renewable energy that considers allocation schemes to evaluate the impact of carbon pricing on economic outcomes and emission decrease. The model analyzes how system marginal prices are determined under different allocation schemes and quantifies trade-offs between carbon and cost under various policy and market conditions. Sensitivity analyses are conducted considering advances in cross-sectoral technologies and various energy and carbon prices. The results show that, unless the dispatch approach is properly aligned with the allocation scheme, improvements in the efficiency of combined heat and power units beyond a certain point can unintentionally increase both indirect emissions and operating costs. Through case studies under diverse scenarios, the study provides practical recommendations for system operators, investors, and policymakers to support affordable and low-carbon energy transitions. The findings underscore the importance of well-designed emission allocation policies and cost-effective investment strategies in achieving climate and energy transition goals.</div></div>","PeriodicalId":56142,"journal":{"name":"Sustainable Energy Grids & Networks","volume":"45 ","pages":"Article 102079"},"PeriodicalIF":5.6,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145738370","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"BESS and PV systems application for optimal microgrid operation with frequency security constraints","authors":"Mehrdad Bagheri-Sanjareh,&nbsp;Marjan Popov","doi":"10.1016/j.segan.2025.102103","DOIUrl":"10.1016/j.segan.2025.102103","url":null,"abstract":"<div><div>Battery energy storage systems (BESSs) have been used in AC Microgrids (AMGs) for frequency control (FC) and energy management (EM). AMGs with low inertia might suffer large frequency deviations with high rates without the required reserve power for FC. This paper proposes a linear model for the optimal operation of grid-connected AMGs considering frequency security constraints. BESS and photovoltaic systems both participate in primary FC (PFC) and EM. PVSs can decrease their generation in power surplus conditions. They can release the energy of their DC-link capacitors in power shortage conditions. Through coordinated use of BESS and PVSs, the required BESS power for PFC decreases considerably, which allows the BESS to participate in EM more effectively and hence reduces the AMG operational cost. Frequency simulation studies show that PVSs can considerably assist BESS for PFC. Moreover, the optimization results show that without PVSs' support, load shedding is unavoidable which increases the AMG operation cost significantly. In this regard, deterministic and stochastic optimization show that PVSs' participation in PFC results in 24 % and 24.2 % reduction in the AMG operation cost compared to those when BESS is only used for PFC. Therefore, the PVSs' assist in PFC, even though short, has large impact on the optimal operation of the AMG.</div></div>","PeriodicalId":56142,"journal":{"name":"Sustainable Energy Grids & Networks","volume":"45 ","pages":"Article 102103"},"PeriodicalIF":5.6,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145840580","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Assessing the role of flexible technologies in the Greek wholesale electricity market under National Energy and Climate Plan targets","authors":"Panagiota T. Kyrimlidou ,&nbsp;Christos K. Simoglou ,&nbsp;Pandelis N. Biskas","doi":"10.1016/j.segan.2025.102090","DOIUrl":"10.1016/j.segan.2025.102090","url":null,"abstract":"<div><div>This paper investigates the impact that the penetration of flexible resources, such as battery energy storage systems, cross-border capacity and the application of load shifting, may have on the Greek wholesale electricity market operation under the main provisions of the recent National Energy and Climate Plan (NECP). A thorough scenario-based analysis of the Greek day-ahead and real-time balancing markets for the year 2030 has been conducted using a specialized market simulation software under finest time granularity to evaluate critical market indicators, including the electricity generation mix, RES curtailments, wholesale market prices, revenues/profits of market participants and CO₂ emissions. Simulation results underscore the significant role that the adopted flexibility resources are expected to bring in the Greek electricity market and power system operation, since they are expected to effectively reduce RES curtailments up to 50 %, reduce conventional gas-fired units’ generation volumes up to 8 % and increase average day-ahead market clearing prices up to 6 %. The combined deployment of all examined flexibility options may improve the environmental footprint of the Greek power system by reducing the annual CO₂ emissions up to 2.9–3.8 %. The findings of this study also highlight the strategic importance of developing balanced flexibility portfolios that combine domestic flexibility resources with regional interconnection upgrades, while providing targeted financial support for newly invested, capital-intensive assets whose market revenues alone cannot ensure their economic viability.</div></div>","PeriodicalId":56142,"journal":{"name":"Sustainable Energy Grids & Networks","volume":"45 ","pages":"Article 102090"},"PeriodicalIF":5.6,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145840562","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Reliability constrained optimization of virtual inertia and battery energy storage system sizing for frequency stability in low inertia power systems","authors":"S. Saha ,&nbsp;M. Elliott ,&nbsp;T.K. Roy ,&nbsp;Amanullah M.T. Oo","doi":"10.1016/j.segan.2026.102130","DOIUrl":"10.1016/j.segan.2026.102130","url":null,"abstract":"<div><div>Increased penetration of renewable energy is depleting grid inertia by replacing synchronous generators, making modern power systems more susceptible to frequency instability during generator outages or large load fluctuations. Virtual inertia support through battery energy storage systems has emerged as a potential solution to address this stability challenge. However, most existing approaches to virtual inertia allocation and BESS sizing are deterministic, relying on fixed parameters or heuristic assumptions that overlook the time-varying and uncertain nature of renewable generation, load demand, and system contingencies. This paper introduces a reliability-constrained stochastic framework to determine the virtual inertia and corresponding BESS capacity required to maintain frequency stability under such uncertainty. The framework integrates Monte Carlo simulation with <span><math><msub><mrow><mi>H</mi></mrow><mrow><mi>∞</mi></mrow></msub></math></span>-norm minimization to ensure that frequency nadir and rate-of-change-of-frequency (RoCoF) limits are satisfied in a predefined proportion of operating scenarios. Reliability is incorporated as a probabilistic constraint, enabling operators to adjust inertia support in line with target reliability levels. A case study based on a modified IEEE 39-bus system demonstrates that the required BESS capacity varies dynamically with renewable output and system inertia, and that higher reliability enhances frequency resilience but with diminishing economic returns. This reliability-driven formulation advances existing practice by linking frequency security, uncertainty, and investment efficiency within a unified planning framework, providing system operators with a practical tool to balance stability assurance and economic viability in low-inertia grids.</div></div>","PeriodicalId":56142,"journal":{"name":"Sustainable Energy Grids & Networks","volume":"45 ","pages":"Article 102130"},"PeriodicalIF":5.6,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147395726","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Evaluation of load-side flexibility supply capability considering source-load interaction in power system operation","authors":"Jinghua Li,&nbsp;Long Luo,&nbsp;Jianfeng Chen,&nbsp;Shanyang Wei,&nbsp;Bo Li","doi":"10.1016/j.segan.2026.102132","DOIUrl":"10.1016/j.segan.2026.102132","url":null,"abstract":"<div><div>The evaluation of load-side flexibility resources (FRs) plays a crucial role in coordinating generation-side variability with demand-side response potential, thereby improving the stability and operational efficiency of power systems with high renewable energy penetration. However, increasing generation uncertainty and heterogeneous load behaviors highlight the need for an integrated evaluation framework that explicitly considers source-load interaction. This paper proposes a comprehensive method for assessing the load-side flexibility supply capability based on coordinated source-load dynamics. A bidirectional interaction framework is first developed, coupling generation-side flexibility characteristics with a refined load response model to quantify the coordinated adjustment potential. An integrated indicator system is then established, covering both performance and economic dimensions. To address the uncertainty and randomness inherent in flexibility evaluation, a two-dimensional (2D) cloud model is introduced to characterize the relationship between flexibility performance and uncertainty under typical scenarios. Comparative experiments using four widely adopted multi-attribute decision-making methods verify that the proposed 2D cloud model exhibits superior discriminative and ranking capabilities. Results indicate that data centers (DCs) provide stable but limited flexibility; electric vehicles (EVs) offer high flexibility potential yet exhibit greater uncertainty; and variable-frequency air conditioners (VFACs) maintain reliable responsiveness but face constraints under high renewable penetration.</div></div>","PeriodicalId":56142,"journal":{"name":"Sustainable Energy Grids & Networks","volume":"45 ","pages":"Article 102132"},"PeriodicalIF":5.6,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147395727","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Dynamic thermal impact of heatwaves on resilience of power system considering transmission line and generators capacities","authors":"Abhishek Kumar Gupta,&nbsp;Kusum Verma","doi":"10.1016/j.segan.2026.102137","DOIUrl":"10.1016/j.segan.2026.102137","url":null,"abstract":"<div><div>With the increasing impact of climate change, heatwaves have become more frequent and pose a growing threat to critical power system components. This paper presents a robust impact analysis of long-term climate warming on the resilience of transmission lines and generators. The proposed methodology dynamically models thermal stress by coupling the IEEE Std. 738–2012 ampacity standard incorporating ambient temperature, wind speed, and solar radiation with temperature-dependent generator derating characteristics. A 20-year daily temperature dataset is generated using a stochastic hybrid heatwave model and processed through a sequential Monte Carlo Simulation (10 annual scenarios) to capture extreme \"tail risks\" rather than relying solely on average conditions. These dynamic thermal constraints are integrated into an AC Optimal Power Flow (AC-OPF) framework to quantify resilience metrics, including Expected Energy Not Supplied (EENS), Loss of Load Expectation (LOLE) and Safe Operation Probability (SOP). The proposed methodology is investigated on IEEE 57-bus system with results showing a consistent degradation of resilience metrics under heatwave scenarios. The system-level analysis quantifies a distinct \"Climate Penalty,\" revealing a 24.37 % increase in unserved energy driven by spatially clustered voltage violations and recurring thermal overloads. Critically, the analysis identifies specific \"bottleneck\" corridors, demonstrating that failures are localized rather than systemic. These findings provide a practical roadmap for grid planners and policymakers by shifting the focus from expensive system-wide upgrades to targeted, cost-effective infrastructure hardening at identified vulnerable nodes.</div></div>","PeriodicalId":56142,"journal":{"name":"Sustainable Energy Grids & Networks","volume":"45 ","pages":"Article 102137"},"PeriodicalIF":5.6,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147395728","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}