Abstract: Methane is an unconventional natural gas in coal seams. Coalbed methane (CBM) migration behavior constitutes a core issue in coalbed methane extraction. However, there is no consensus on the gas migration mechanism of dual-porosity coal seams. To elucidate the mechanism of gas migration and visualize the dynamic migration process of gas, two dual-porosity borehole gas seepage models were established. Specifically, the pressure gradient drives gas in the fracture, and gas in the coal matrix is driven by the pressure gradient and density gradient respectively. The finite difference method is employed to solve both models. Through the self-developed numerical simulation software, the gas pressure distribution, gas emission velocity, and gas accumulation emission amount were obtained. By comparing the numerical results with the field-measured data, the accuracy and disparities between the two models were investigated and discussed. The results show that: ① In the initial stage of extraction, both models are predominantly governed by Darcy flow, and their gas emission velocity and cumulative gas emission quantity are substantially in consonance with the field data. In the subsequent stage, the gas within the coal matrix assumes a dominant role in gas migration. ② Due to the existence of free gas, the variation range of gas pressure in borehole in the density gradient model is larger than that in the pressure gradient model. The diffusion behavior in coal matrix is more consistent with the density gradient model in coal matrix. ③ The gas emission rate of the borehole exhibits a positive correlation with the original gas pressure, porosity, and fracture permeability coefficient, and a negative correlation with the matrix radius. The dual-porosity borehole gas transport model driven by the gas pressure gradient in fracture and free gas density gradient in coal matrix can reflect the physical behavior of borehole gas transport in coal reservoir more truly and accurately.