Device and method for measuring two-phase relative permeability curve of unconventional oil reservoir are provided, 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. Two-phase relative permeability curve of unconventional oil reservoir can be measured accurately through the device.

A system and method for surface characterization of a porous solid or powder sample using flowing gas include mass flow controllers configured to deliver a controllable mass flow of a carrier gas and adsorptive gas to vary concentration of the adsorptive gas flowing through at least one measurement channel containing a sample cell. A concentration detector downstream of the sample cell provides a signal indicative of the adsorptive gas concentration to a controller that determines the amount of adsorptive gas adsorbed and/or desorbed to characterize the surface area, pore volume, pore volume distribution, etc. of the sample material. The detector may include a housing, heat exchanger, thermal conductivity detector, and a temperature regulator.

A method and a system for measuring the pore structure of tight sandstone are provided. The method comprises the following steps: carrying out the desorption experiment of a core sample saturated by a specific gas containing isotope element to obtain the pressure of the specific gas and the total isotope ratio at each sampling moment; acquiring a single isotope ratio of each pore diameter at each sampling moment according to a physical model containing pore diameter parameter and the pressure of the specific gas at each sampling moment; and obtaining the proportion of a pore of each pore diameter in the core sample. The method and the system for measuring the pore structure of the tight sandstone provided by the disclosure can quickly obtain the pore distribution of the tight sandstone without damaging a sample.

A method for surface characterization of a porous solid or powder sample using flowing gas includes a controller that controls mass flow of a carrier gas and an adsorptive gas to form a mixture having a target concentration of the adsorptive gas over the sample, determining adsorptive gas concentration based on signals from a detector disposed downstream of the sample, automatically repeating the controlling and determining steps for a plurality of different target concentrations, and generating an isotherm for the sample based on the adsorptive gas concentration for the plurality of different target concentrations. The method may include immersing the sample in liquid nitrogen to cool the sample for all, or at least a portion of each of the different target concentrations. The target concentrations may vary from less than 5% to greater than 95%, and may vary in a stepwise manner.

An evaluation method for different types of pore evolution in shale is related, which is applied to the field of unconventional oil and gas research. As the shale depth or maturity increases, different types of pores (including intergranular pores, intragranular pores, organic pores and fractures) developed in shale are constantly changing, which is important for shale oil and gas accumulation. The present invention starts from the high-resolution scanning electron micrography of shale, and respectively extracts the areal porosity of different types of pores based on the division criteria of different types of pores and pore identification in the established shale, and combines the low-temperature N.sub.2, CO.sub.2 adsorption experiments and the high-pressure mercury intrusion experiments to obtain the total pore volume and establish the evolution chart of different types of pores. The proposed method has an important application value for the exploration of unconventional shale oil and gas resources.

This invention relates to a gas sorption screening device and a method for gas sorption screening. It allows assessment of whether a substance is porous to a particular gas or vapour; the generation of simple low-resolution isotherm profiles; and provides indications on gas selectivity.

Provided is a method of calculating a tortuous hydraulic diameter of a porous medium for laminar flow and turbulent flow considering a geometric feature and a friction loss feature. A method of calculating a tortuous hydraulic diameter of a porous medium, according to an embodiment of the present invention, includes providing porosity and a specific surface area of a porous medium, calculating a hydraulic diameter of the porous medium by using the porosity and the specific surface area, calculating tortuosity of the porous medium, and calculating a tortuous hydraulic diameter corresponding to a function of tortuosity, by using the hydraulic diameter and the tortuosity of the porous medium.

A system and method for surface characterization of a porous solid or powder sample using flowing gas include mass flow controllers configured to deliver a controllable mass flow of a carrier gas and adsorptive gas to vary concentration of the adsorptive gas flowing through at least one measurement channel containing a sample cell. A concentration detector downstream of the sample cell provides a signal indicative of the adsorptive gas concentration to a controller that determines the amount of adsorptive gas adsorbed and/or desorbed to characterize the surface area, pore volume, pore volume distribution, etc. of the sample material. The detector may include a housing, heat exchanger, thermal conductivity detector, and a temperature regulator.

An evaluation method for different types of pore evolution in shale is related, which is applied to the field of unconventional oil and gas research. As the shale depth or maturity increases, different types of pores (including intergranular pores, intragranular pores, organic pores and fractures) developed in shale are constantly changing, which is important for shale oil and gas accumulation. The present invention starts from the high-resolution scanning electron micrography of shale, and respectively extracts the areal porosity of different types of pores based on the division criteria of different types of pores and pore identification in the established shale, and combines the low-temperature N.sub.2, CO.sub.2 adsorption experiments and the high-pressure mercury intrusion experiments to obtain the total pore volume and establish the evolution chart of different types of pores. The proposed method has an important application value for the exploration of unconventional shale oil and gas resources.

A system and method for testing of skin electroporation using simulations of human skin has been described. The system is using a simulation protocol to provide an in-silico design of skin's upper layer stratum-corneum (SC) at molecular level. This model is then further used to design the skin electroporation strategy. An external electric field was applied across the lipid bilayer to form a pore in the lipid bilayer. The pore size and pore growth rate was calculated depending on the applied external electric field. The generated pore was then stabilized by varying the external electric field. Further, on removing the external electric field, the reformation of lipid bilayer and self-healing of human skin was also achieved. In another embodiment, the system is also configured to perform the virtual testing of a drug permeation through skin in presence of external electric field.