Both gas and water transport exist in nanopores during the development of shale gas reservoirs (SGRs). The study of two-phase flow is conducive to the improvement of recovery for gas production. And it almost exists in the whole progression of SGR development. Based on the Beskok’s model, Sun et al. built a new apparent permeability gas model with considering real gas effect (Sun in International Journal of Heat and Mass Transfer 115:1008–1019, 2017), surface diffusion, stress dependence, the shape of different types of nanopores, and water film effect. Feng et al. studied the adsorption behavior of clay minerals in shale by measuring the adsorption isotherms of water (Feng in Applied Clay Science 155:126–138, 2018). Song et al. established water and gas migration models in shale nanopores, respectively (Song in Advances in Water Resources 130:300–313, 2019). The gas phase model in inorganic pores considers slippage effect, while the gas phase model in organic pores considers surface diffusion. Li et al. established two-phase gas–water relative permeability model with an interface effect grounded by the Poiseuille law (Li in International Journal of Coal Geology 159:71–81, 2016), and verified the accuracy of the model. Shen et al. modeled the flow process of gas and water in hydraulic fracturing shale reservoirs through CMG software (Shen in Journal of Natural Gas Science and Engineering 35:726–735, 2016). However, the flow mechanisms considered by the CMG software is not perfect due to the limitations of CMG, and it cannot follow up with the latest study in this area.