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• CO 2 flooding and DME-assisted CO 2 flooding were experimentally studied. • Experiments were performed with different shale samples. • DME-assisted CO 2 flooding has higher oil recovery compared to CO 2 flooding. CO 2 injection into shale oil reservoirs can effectively enhance recovery while simultaneously realizing geological storage. However, shale oil recovery by CO 2 injection remains low. In this paper, classification and evaluation standards for shale oil reservoirs were established. Based on this, comparative experiments between pure CO 2 flooding and dimethyl ether (DME)-assisted CO 2 flooding were conducted, supplemented by nuclear magnetic resonance testing. The microscopic production characteristics of shale oil under different injection methods were analyzed. The effects of injection pressure, gas injection volume, and DME concentration on oil recovery were studied, and the potential of DME-assisted CO 2 flooding was explored. The results show three types of shale samples: I, II, and III, with their corresponding physical properties, pore-throat structures, and percolation capacities decreasing in the same order. With the addition of DME, the CO 2 solubility increased, while the produced oil viscosity significantly decreased. DME-assisted CO 2 flooding has higher recovery compare with CO 2 flooding. The increase is more significant as pressure increases. The increase in ultimate recovery was the largest for type III samples. In addition, regardless of whether pure CO 2 flooding or DME-assisted CO 2 flooding was applied, a higher injection pressure and injection volume mean higher recovery. The increase by DME-assisted CO 2 flooding is much greater than that by pure CO 2 flooding. During the miscible stage, the recovery is greater than that during the immiscible stage. The recovery increased with increasing DME molar concentration and then slowed down; therefore, the recommended molar concentration of DME in the mixed gas is 20 mol%. The research results provide new methods and ideas for enhancing shale oil recovery and realizing geological storage by CO 2 injection. [ABSTRACT FROM AUTHOR]

• CO 2 fracturing requires the low initial fracturing pressure to create multiple fracture patterns and a complex fracture network. • CO 2 fracturing changes the microscopic pore throat structure of shale. • CO 2 fracturing in shale reservoirs causes deterioration of the mechanical properties of the rock. • The mechanism of CO 2 fracturing is different for different phases. Continental shale reservoirs are resilient, and the fracture networks formed by conventional fracturing technologies are limited in size. The CO 2 fracturing technology can be adapted for the development of continental shale reservoirs. However, shale reservoirs have strong heterogeneity in the microscopic pore-throat system. The fracture extension and micro-mechanical mechanisms of CO 2 fracturing in shale reservoirs are not defined. To study the CO 2 fracturing mechanism in shale reservoirs, typical core samples were selected from the Chang 7 shale reservoir of the Yanchang Formation in the Ordos Basin. Moreover, true triaxial simulated fracturing, CO 2 -fluid-rock microscopic damage, and rock mechanics experiments were conducted before and after CO 2 fracturing. The experimental results were used to analyze the fracture initiation, steering, extension, and stopping criteria under different CO 2 fracturing methods, quantitatively characterize the damage degree of the microscopic pore-throat system in shale reservoirs after CO 2 -fluid-rock interaction, evaluate the deterioration mechanism of CO 2 fracturing on the mechanical properties of the shale reservoir, and clarify the complex fracture network formation mechanism as well as microscopic and mechanical control effects under different CO 2 fracturing methods in shale reservoirs. The results show that CO 2 -fracturing shale reservoirs have lower fracture initiation pressure. The main fracture communicates with the natural bedding planes of the shale, and various fracture modes, such as tensile damage, shear damage, and combined tensile-shear damage, are apparent. The degree of damage to the microscopic pore-throat system by the CO 2 -fluid-rock interaction ranges from 7.78% to 9.28%. The longitudinal and transverse wave velocities of the rock are reduced, Young's modulus and compressive strength are decreased, and the mechanical properties of the rock deteriorate. The L-CO 2 fracturing of shale forms large-scale fractures with high fracture complexity. The microscopic damage was dominated by physical damage, the damage of liquid CO 2 (L-CO 2) is more significant for medium and large pores. The deterioration of the rock mechanical properties was evident, and the rock brittleness index was reduced. Small-scale fractures form owing to the SC-CO 2 fracturing shale reservoirs. Microscopic damage is dominated by chemical damage, strong dissolution-acidification. The structural damage of supercritical CO 2 (SC-CO 2) is evident for small pores. Rock brittleness is higher after CO 2 fracturing. The results of this study reveals the fracture expansion mechanism of CO 2 fracturing shale reservoirs and the control law of microscopic and mechanical damage effects on fracture network formation. This study enriches the basic theoretical system and has high economic, environmental and scientific value for enhanced oil recovery in shale reservoirs. [ABSTRACT FROM AUTHOR]