A method is disclosed for demonstrating the cleansing efficacy of a personal care product or a component thereof, the method comprising: (i) selecting a first portion of a porous article capable of allowing a gas to pass through its pores, wherein the porous article is connected to a source of said gas and immersed in a liquid while the source releases said gas which flows out of said pores to generate gas bubbles; (ii) treating the first portion of the porous article with contaminants; (iii) treating the first portion of the porous article with the personal care product or the component thereof, wherein a second portion of the porous article is selected in step (i); the second portion is also treated with contaminants in step (ii); and the second portion is treated with a comparative or placebo product in step (iii); and wherein following step (iii) the method comprises a step (iv) of assessing a change of the treated first portion relative to untreated article and/or relative to the treated second portion, the change is the amount of gas bubbles released from the porous article.

Method of identifying a valid flow path includes: performing fluid analysis of a porous body, which is ought to have inflow surface and outflow surface, based on structure data representing a 3-dimentional structure of the porous body to generate data indicating at least a pressure distribution of a fluid in a flow path in the porous body; and identifying a valid flow path that allows the fluid to flow from the inflow surface to the outflow surface based on a gradient of pressure values along a flow direction of the fluid in the flow path.

An evaluation method for hydrogen-bearing components, porosity and pore size distribution of organic-rich shale is provided, relating to a technical field of oil and gas development. The evaluation method includes steps of: according to differences among NMR (nuclear magnetic resonance) T.sub.1-T.sub.2 maps of kerogen, oil-adsorbed kerogen, clay minerals of different water-containing conditions, shale, dry shale sample, oil-saturated shale sample and water-saturated shale sample, establishing a classification scheme for each hydrogen-bearing component and a quantitative characterization method for fluid components of the organic-rich shale; with a T.sub.2 distribution of the organic-rich shale after being saturated with oil as a target and a T.sub.2 distribution of the dry shale sample as a basement, subtracting the basement, and obtaining a T.sub.2 distribution of oil in pores; and based on the T.sub.2 distribution of oil in the pores, evaluating the porosity and the pore size distribution of the organic-rich shale. Compared with a conventional method, the present invention shows relatively high innovativeness and credibility, which is beneficial to perfecting analysis of NMR in shale petrophysical measurement.

A method of detecting at least a blockage status in a porous member separating a measurement chamber of a device including a gas sensor positioned within the measurement chamber which is responsive to an analyte in an ambient environment to be sampled, includes emitting pressure waves from a pressure wave source which travel within the measurement chamber, measuring a first response via a first sensor responsive to pressure waves positioned at a first position within the measurement chamber, measuring a second response via a second sensor at a second position, different from the first position, and in fluid connection with the pressure wave source, determining the blockage status of the porous member based upon a functional relation of the first response and the second response.

An experiment system and transparent experiment method for replicating fluid displacement in a pore structure of a natural rock mass are provided. The natural pore structure is extracted and a digital porous model corresponding to the natural rock mass is reconstructed with the image processing method. Based on the digital porous model, a three-dimensional pore structure model with a transparent and visible internal structure is printed by a 3D printing device, such that the pore space inside the three-dimensional pore structure model is visible. In this way, the whole fluid flow during the displacement-seepage process within the natural rock mass can be replicated and visually observed from the outside when performing the displacement-seepage experiment. Further, temperature, flow rate, and pressure can be accurately controlled, to replicate various experiment conditions, so as to perform quantitative analysis on distribution features of a seepage field and a fluid speed field.

A synthetic source rock including roasted tea powder and inorganic material. A technique for preparing the synthetic source rock, including grinding tea leaves to give tea powder, roasting the tea powder at a roasting temperature to give a roasted tea powder, and determining composition and porosity of the roasted tea powder.

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 method of determining absolute permeability in carbonates without upscaling computations includes performing a nuclear magnetic resonance (NMR) analysis and a mercury-injection capillary-pressure (MICP) analysis on at least three samples from carbonate rock of a set of representative regions to determine an experimental permeability, where each of the representative regions have properties related to the porosity and pore-throat size of the carbonate rock. A series of low resolution X-ray scans and a series of high resolution X-ray scans are performed on the same three samples of the carbonate rock of the set of representative regions. Permeability simulations are performed on the same three samples of the carbonate rock of the set of representative regions to determine a computed permeability. The experimental permeability and the computed permeability are then compared to provide computationally manageable and reasonable estimates of the absolute permeability of the carbonate rock.

A system and method for high-throughput, high-resolution gas sorption screening are provided. An example system includes a sample chamber with a hermetic seal and a heat exchanger system. The heat exchanger system includes a heat exchanger disposed in the sample chamber, a coolant circulator fluidically coupled to the heat exchanger, and a sample plate comprising sample wells in contact with the cooling fluid from the coolant circulator. The system also includes a gas delivery system. The gas delivery system includes a gas source and a flow regulator. A temperature measurement system is configured to sense the temperature of the sample wells.

A method for analysing a bonding between two aeronautical parts. The method includes the steps of a) applying a release agent to a first surface to be bonded of a first part and to a second surface to be bonded of a second part, b) applying an adhesive to at least one of the first and second surfaces and positioning these surfaces on top of each other, the adhesive forming an adhesive film after polymerisation, c) separating the parts from each other and removing the adhesive film in one piece, d) analysing the adhesive film. The invention also relates to a method for bonding two aeronautical parts.