Abstract: China possesses abundant deep coalbed methane (CBM) resources, but their efficient development is hindered by complex geological structures and reservoir conditions. The H Block in the Qinshui Basin exhibits significant variations in fracturing effectiveness within its deep coal reservoirs, for which existing evaluation methods are inadequate. This study aims to establish a comprehensive fracability evaluation methodology for deep coal reservoirs in structurally complex areas, to accurately identify fracturing "sweet spots", and to provide theoretical and technical support for the classified stimulation and efficient development of deep CBM resources. This research focuses on Coal Seam No. 15, with a burial depth of 1352−1921 m in the H Block. It integrates multi-source data including geology, logging, experimental tests, and fracturing engineering. Key geological parameters—fracture development degree, brittleness index, fracture toughness, in-situ stress difference coefficient, and coal structure index—were systematically quantified using coal mechanics tests, in-situ stress field analysis, and advanced techniques like CT scanning and XRMI imaging. The Analytic Hierarchy Process (AHP) was employed to determine parameter weights, leading to the construction of a mathematical model for a Comprehensive Fracability Index (FI), enabling quantitative evaluation and zoning of fracability within the study area. Results showed that ① The key geomechanical characteristics of Coal Seam No. 15 were revealed: the natural fracture development index ranges from 0.26 to 1.16, showing strong spatial heterogeneity; the brittleness index is primarily below 0.4; distributions of Type I and Type II fracture toughness are consistent; the horizontal principal stress difference coefficient is between 0.04 and 0.20; and the coal structure is dominated by fragmented-granular coal. ② Based on the FI values (0.35−0.76), the study area was classified into three fracability types: Type I (FI > 0.6, Preferred), Type II (0.45 < FI < 0.6, Good), and Type III (FI < 0.45, Fair), with their spatial distribution patterns clearly identified. ③ Microseismic monitoring and production data validated the zoning reliability: Type I areas achieved the highest fracture length per unit fluid volume (0.043 m/m³), with gas encountered 158 days after fracturing and a stable production rate of 4 044 m³/d. Type II and Type III areas showed values of 0.042 m/m³ and 0.037 m/m³, and stable production rates of 2 036 m³/d and 1731 m³/d, respectively, demonstrating a positive correlation between the fracability index and development outcomes. The established “geology-engineering” integrated fracability evaluation system effectively overcomes the limitations of traditional methods and accurately characterizes the fracturing potential of deep coal reservoirs in structurally complex areas. This achievement provides a reliable decision-making tool for well placement optimization and differentiated fracturing design in deep CBM development, holding significant application value for promoting the profitable development of similar complex reservoirs.