Device and method for measuring two-phase relative permeability curve of unconventional oil reservoir

A method for measuring two-phase relative permeability curve of unconventional oil reservoir, characterized in that the method comprises:

• S1, selecting a target core, and making at least one two-dimensional porous seepage microscopic model according to structure of the target core;
• S2, determining starting pressure gradient of the two-dimensional porous seepage microscopic model and pressure loss caused by boundary effect of the two-dimensional porous seepage microscopic model;
• S3, using a device for measuring two-phase relative permeability curve of unconventional oil reservoir;
• wherein, the device comprises:
• two-dimensional porous seepage microscopic model;
• injection components connected to inlet end of the two-dimensional porous seepage microscopic model;
• confining pressure components arranged outside the two-dimensional porous seepage microscopic model;
• a camera component arranged on one side of the two-dimensional porous seepage microscopic model;
• back pressure components connected to outlet end of the two-dimensional porous seepage microscopic model;
• and outlet pressure measuring and recovery components connected to outlet end of the two-dimensional porous seepage microscopic model, to obtain relative permeability curve parameters through non-steady-state method;
• the relative permeability curve parameters comprise:
• oil phase relative permeability, water phase relative permeability, and oil saturation;
• wherein the two-dimensional porous seepage microscopic model in the device for measuring two-phase relative permeability curve of unconventional oil reservoir is made by step S1;
• and
• S4, drawing relative permeability curve according to the relative permeability curve parameters;
• wherein, step S2 comprises:
• S21, calculating proportions of different pore diameters in the two-dimensional porous seepage microscopic model, and calculating characteristic capillary diameter corresponding to the two-dimensional porous seepage microscopic model by harmonic mean method;
• S22, making a corresponding capillary model according to the characteristic capillary diameter;
• S23, using the capillary model to measure thickness of boundary layer when oil phase flows under different pressure gradients, and drawing a curve of thickness of boundary layer changing with pressure gradients;
• and
• S24, using the capillary model to measure flow rate of oil phase under different pressure gradients and flow rate of water phase under different pressure gradients, and determining starting pressure gradient of the oil phase and starting pressure gradient of the water phase.