An Integrated Techno-Economic Framework for Optimal Microgrid Design: An Australian Case Study
統合的技術経済的枠組みによる最適マイクログリッド設計：オーストラリアのケーススタディ (AI 翻訳)
Mohamed Atef, Sanath Alahakoon, Umme Mumtahina, Peter Wolfs, Tamer Khatib, Moslem Uddin
🤖 gxceed AI 要約
日本語
本研究は、遠隔地域向けマイクログリッドの最適設計のための統合的技術経済フレームワークを提案し、オーストラリアの1000世帯コミュニティに適用。PV、風力、バッテリー、ディーゼル、系統、水素を含むハイブリッド構成を評価し、感度分析により最適設計が財務・技術・政策要因で非線形に変化することを示す。
English
This paper develops a techno-economic framework for designing optimal microgrids for remote communities, combining simulation, dispatch modeling, and lifecycle costing. Applied to a 1000-household case in Australia, it evaluates hybrid systems including PV, wind, battery, diesel, grid, and hydrogen. Sensitivity analysis reveals nonlinear shifts in optimal design under varying financial, technical, and policy assumptions. The framework supports comparison of hydrogen and battery solutions for low-emission microgrid planning.
Unofficial AI-generated summary based on the public title and abstract. Not an official translation.
📝 gxceed 編集解説 — Why this matters
日本のGX文脈において
日本の離島や山間部でも同様のエネルギー課題があり、本フレームワークは水素統合やレジリエンス向上に寄与する可能性がある。ただし、日本の電力市場制度や補助金政策を考慮した調整が必要。
In the global GX context
This paper contributes to global GX context by providing a comprehensive decision-support tool for renewable microgrids, integrating hydrogen and carbon pricing. It addresses the need for robust planning under uncertainty, relevant for energy transition in remote areas worldwide.
👥 読者別の含意
🔬研究者:Provides a rigorous sensitivity analysis framework for microgrid optimization, useful for energy system modelers.
🏢実務担当者:Offers a tool for evaluating hybrid microgrid configurations, including hydrogen, for remote community energy planning.
🏛政策担当者:Demonstrates the impact of carbon pricing and financial incentives on optimal microgrid design, informing policy for rural electrification.
📄 Abstract（原文）
Reliable and affordable electricity supply remains a challenge for remote and regional communities, motivating the deployment of renewable-based microgrids supported by flexible storage and advanced planning methods. This paper proposes an integrated techno-economic framework for optimal microgrid design and robustness assessment, and applies it to a 1000-household residential community in Rockhampton, Queensland (Australia). The framework links time-series simulation, dispatch-based operation, and lifecycle costing to evaluate hybrid configurations comprising photovoltaic and wind generation, battery storage, diesel backup, grid exchange, and an optional hydrogen subsystem (electrolyzer--hydrogen storage--fuel cell). Key indicators include net present cost (NPC), cost of energy (COE), renewable penetration, energy purchased/sold, and emissions-related outcomes. To avoid conclusions that depend on a single set of assumptions, the study performs systematic sensitivity analysis across financial, technical and policy drivers: discount rate, technology capital costs, fuel price, load uncertainty, renewable resource variability, carbon pricing/emissions cost, and grid outage duration, supplemented by a no-hydrogen attribution case. The results demonstrate that several sensitivity dimensions induce nonlinear shifts in the optimal design, including breakpoints where capital-intensive renewable--storage expansion becomes economically preferable. The proposed framework enables transparent comparison of hydrogen-enabled and battery-centric solutions and provides planning guidance for resilient, low-emission community microgrids under Australian operating conditions.
🔗 Provenance — このレコードを発見したソース
- arXiv https://arxiv.org/abs/2606.03783first seen 2026-06-03 04:11:14
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