# Hybrid Wind-Redox Flow Battery System for Decarbonizing Off-Grid Mining Operations
## 1 Introduction
[PERSON] and [PERSON] [41] emphasize that assessing the techno-economic feasibility of RFBs remains a significant challenge for large-scale projects, where system costs must be evaluated based on material composition, system design, and modeling methodologies. [PERSON] et al. [42] emphasize the need for a deeper understanding of the technical and economic performance parameters of flow battery technologies to enhance their commercial viability. [PERSON] et al. [43] further highlight that cost challenges remain a significant barrier to the widespread adoption of RFBs. [PERSON] et al. [44] advocate for optimization strategies in vanadium redox flow battery systems, particularly in reducing material costs, optimizing bipolar plate resistances, and improving energy storage media efficiency. To support cost reductions, [PERSON] et al. [45] developed a cost model for redox flow batteries, revealing that the energy-to-power ratio of the storage system is a crucial factor in minimizing costs across various battery chemistries. Additionally, LCOE reductions are influenced by integrating advanced materials (e.g., novel alloys), improved manufacturing processes, and higher nominal power capacities [46]. Currently, the levelized cost of energy (LCOE) for redox flow batteries is estimated at CAD 0.0503/kWh [29]. [PERSON] et al. [25] report a payback period of 7.33 years for a microgrid equipped with a vanadium redox flow battery, further reinforcing the economic feasibility of this technology. In the literature, LCOS models for redox flow batteries have been widely utilized to evaluate cost-effectiveness across different storage applications [38; 40]. This study evaluates the feasibility of integrating a redox flow battery storage system with an expanded wind farm at the Ragland mining site. This research utilizes a MATLAB R2024b-based simulation model to evaluate the technical, economic, and environmental impacts, with a focus on diesel savings, CO2 emissions reduction, and system reliability. Unlike previous studies focusing on standalone storage systems, this research integratesa comprehensive techno-economic analysis, comparing multiple wind-battery hybrid scenarios. Specifically, it examines how different battery capacities (80 MWh, 120 MWh, 160 MWh) and wind penetration levels (45-75%) affect the Levelized Cost of Energy (LCOE) and Levelized Cost of Storage (LCOS), key determinants of project feasibility [26; 44]. The key research questions guiding this study are as follows:  
1. What is the optimal configuration of wind energy and redox flow storage to maximize diesel savings at the Raglan mining site? 2. What are the economic implications of integrating large-scale redox flow batteries, particularly in Arctic conditions? 3. How does energy storage improve grid stability, and what policy incentives could enhance financial feasibility? This article is part of a broader research initiative exploring various energy storage technologies to support the decarbonization of remote mining operations in northern Quebec. In addition to the redox flow battery system analyzed in this study, parallel investigations are underway on battery energy storage systems (BESS), hydrogen storage, and PHSP systems [47; 48]. These complementary studies evaluate each option based on technical performance, economic viability, and environmental compatibility within off-grid Arctic contexts. However, due to the ongoing comparative analysis, this paper focuses solely on the techno-economic feasibility of implementing a redox flow battery system in the Raglan hybrid electricity network. Building on this context, the present work investigates the potential for significantly reducing or even eliminating diesel dependency at the Raglan mine by integrating a wind farm coupled with a redox flow battery storage system. Specifically, it examines how this hybrid \"Diesel Thermal Power Plants-Wind Farm-redox battery\" configuration can address the intermittency of wind energy and maintain a stable electricity supply across the mine's 25 kV-G network.