Shale reservoirs have more complex and more diverse pore spaces than conventional oil reservoirs, showing typical multi-scale characteristics. The accurate description of the microscopic pore structure of reservoirs and the accurate characterization of shale oil flow low are extremely important for the efficient development of shale reservoirs. In this work, X-ray computed tomography (XCT) imaging and scanning electron microscope experimental research on the rock sample from Shengli Oilfield are utilized to depict the multi-scale micro pore structure of shale. Considering the slip and adsorption on the rock surface, the shale oil flow model in the digital core is established based on the Navier-Stokes equation. The results show that the proportion of pores and cracks in shale rock samples is 20.89%, of which more than 50% of the pore radii are less than 50 nm. The proportion of organic matter is 4.52%, and the less developed pores in organic matter indicate the less maturity of shale samples. The adsorption on the surface of organic pore reduces the permeability of shale oil and has a greater impact on the flow of shale oil, especially in shale reservoirs with more organic pores. Furthermore, the slippage on the surface of the inorganic pore increases the permeability of shale oil. In shale reservoirs with more inorganic pores, the slippage has an important influence on the flow of shale oil.