The heterogeneity of the pore structure of coal reservoirs affects the desorption and diffusion characteristics of coalbed methane, and determining its distribution law is conducive to improving the theory of coalbed methane development. The central and eastern parts of the Qinshui Basin are rich in coalbed methane resources, but the heterogeneity characteristics of the pore structure of coal reservoirs are not clear. NMR has the advantages of being fast, non-destructive and full-scale, and multifractal can describe the self-similarity of NMR T2 curve at different scales so as to analyze the complexity of pore distribution. Based on this, 15 samples with different coal ranks were collected from the central and eastern Qinshui Basin (R_o,max between 1.54 and 2.78%), and quantitative pore characterization experiments such as low-field nuclear magnetic resonance (LF-NMR) and low-temperature liquid nitrogen adsorption (LTN₂A) were conducted. Based on multifractal theory, the heterogeneity law of pore structure was quantitatively evaluated, and its influencing factors were elucidated. The results showed that the BJH pore volume of coal samples in the study area ranged from 0.0005–0.0028 cm³/g, with an average of 0.0014 cm³/g, and the BET specific surface area was 0.07–2.52 m²/g, with an average of 0.41 m²/g. The NMR T₂ spectrum peaked at 0.1–1, 10–100 and 100–1000 ms, and the spectrum was mostly bimodal or trimodal, indicating that pores of different pore sizes were developed. There were great differences in the pore structure of different coal ranks; high-rank coal was dominated by micropores, and the proportion of mesopores and macropores of medium-rank coal was higher. The pore structure of coal samples showed obvious multifractal characteristics, and the fractal characteristics of the sparse region (low-value information) were more significant; they dominated the pore distribution and had a stronger influence on the distribution of pore space. Pore structure heterogeneity is closely related to the degree of coalification, and with the increase in coalification, it is closely related to coal lithotype and quality, and high mineral and inertinite contents lead to the enhancement of pore structure heterogeneity in coal reservoirs, while R_o,max, M_ad and vitrinite group contents have opposite effects. The research results provide theoretical guidance for the subsequent exploration and development of coalbed methane in the region.

Permeability variations during coalbed methane (CBM) production remain a critical research focus. However, existing studies have primarily concentrated on nearly horizontal reservoirs, with limited in-depth analyses of the dynamic evolution of permeability in steeply inclined coal reservoirs (SICRs) (>45°). This study examined the dynamic permeability characteristics across different reservoir dip angles, comparing variations in the up-dip (UD) and down-dip (DD) directions of SICRs and investigating their controlling mechanisms. The results indicate an asymmetry in permeability changes between UDs and DDs, with UDs generally exhibiting a greater amplitude of variation. The reservoir dip angle exerts a more pronounced influence on DD permeability changes, primarily through its effects on effective stress (ES) and matrix shrinkage (MS). Specifically, a reduction in the negative impact of ES in the UD enhances the overall reservoir permeability, whereas a reduction in the positive effect of MS in the DD leads to a more significant permeability decline. The comparatively smaller increase in DD permeability contributes to distinct evolutionary trends in the permeability between UDs and DDs. These dynamic permeability changes in SICRs have a more substantial impact on CBM production, particularly in low-strength and low-rank coal reservoirs. The findings of this study provide valuable insights for optimizing CBM production strategies in SICRs.