The present invention provides a method for estimating hydrocarbon saturation of a hydrocarbon-bearing rock from a resistivity log and a rock image. The image is segmented to represent either a pore space or solid material in the rock. An image porosity is estimated from the segmented image, and a corrected porosity is determined to account for the sub-resolution porosity missing in the image of the rock. A corrected cementation exponent of the rock is determined from the image porosity and the corrected porosity and is used to estimate the hydrocarbon saturation. A backpropagation-enabled trained model can be used to segment the image. A backpropagation-enabled method can be used to estimate the hydrocarbon saturation using an image selected from a series of 2D projection images, 3D reconstructed images and combinations thereof.

A performance evaluation method for elastic material including rubber or elastomer, the method includes a step of applying a strain to a test piece made of the elastic material to form at least one void inside the test piece, a step of obtaining projected images of the test piece by irradiating the test piece with X-rays at a plurality of times after the at least one void is formed, and a step of obtaining a volume change of the at least one void between the plurality of times based on the projected images, as one of indexes of performance.

To separate porosity from surface roughness, length scales for pore size and surface roughness are identified. These length scales are determined from surface roughness measurements and confirmed via NMR pore body calculations and pore size capillary pressure measurements. A filter removes pore contribution to surface roughness measurements and delivers intrinsic surface roughness. Additional filters and methods determine the minimum magnification on which to base surface roughness calculation, based on size of the field of view and where measured surface roughness approaches intrinsic surface roughness as magnification increases but larger magnification increase sampling time and difficulty. Sample irregularities, such as saw marks, are also filtered out or determined to be too large to remove via filter and another area of measurement is located. With the pore corrected quantification of surface roughness, surface relaxivity and pore distribution can be calculated with greater accuracy.

Determination of transport phenomena properties in porous media is one major objective of core analysis studies in petrophysics, reservoir engineering, and groundwater hydrology. Porosity measurement may be considered as a key factor to identify the hydraulic performance of a low permeable porous medium (e.g. rock or concrete). Additionally, the rate of absorption under pressure depends on the permeability, which is related to the connectivity between the existing pores within the porous structure. An alternative Gas Expansion Induced Water Intrusion Porosimetry (GEIWIP) method and apparatus is useful to measure the total porosity and pore size distribution, using a gas/water intrusion apparatus for water tight materials.

Systems and methods are disclosed for using downhole plasma discharge effects to determine porosity and/or permeability of formation material. In some embodiments, a method includes determining a concentration of at least one chemical reaction product in a drilling fluid that has interacted with a plasma discharge proximate formation material. A relation between arc and spark of the plasma discharge is determined based, at least in part, on the at least one chemical reaction product, and at least one of porosity and permeability of the formation material is determined based, at least in part, on the relation between arc and spark.

The present invention provides a composite oxide that can achieve a high low-temperature output characteristic, a method for manufacturing the same, and a positive electrode active material in which the generation of soluble lithium is suppressed and a problem of gelation is not caused during the paste preparation. A positive electrode active material for non-aqueous electrolyte secondary batteries, including a lithium-metal composite oxide powder including a secondary particle configured by aggregating primary particles containing lithium, nickel, manganese, and cobalt, or a lithium-metal composite oxide powder including both the primary particles and the secondary particle. The secondary particle has a porous structure inside as a main inside structure, the slurry pH is 11.5 or less, the soluble lithium content rate is 0.5 [% by mass] or less, the specific surface area is 3.0 to 4.0 [m.sup.2/g], and the porosity is more than 50 to 80 [%].

A method for determining porosity of a part is provided. The method includes: determining scan data of the part, the scan data including data of a plurality of sequential segments; determining a background model for the part, the scan data, or both; and determining a bulk porosity based on a difference between the scan data and the background model.

A method for estimating characteristics of a ceramic fired body, the method including: preparing a ceramic fired body by firing a formed green body; measuring a color of the ceramic fired body; and with use of a correlation between the color and at least one characteristic selected from a group consisting of a porosity, a pore diameter, and a thermal expansion coefficient previously determined for a ceramic fired body having a same composition as that of the ceramic fired body, estimating the at least one characteristic of the ceramic fired body from the color of the ceramic fired body, measured in the previous step.

Method and system for determining a confinement size in a porous media, including subjecting the media to a substantially uniform static magnetic field, applying a magnetic resonance pulse sequence to the media, detecting magnetic resonance signals from the media, determining non-ground eigenvalues from the magnetic resonance relaxation spectrum, and determining a confinement size of the media from the eigenvalues.

Methods and systems for determining pore-volume of a fracture in a core plug. The method includes developing a grid block model constrained by fracture porosity estimated from a mechanical laboratory test, aperture calculation, and discrete fracture model validation. The method further includes determining the natural fracture porosity and pore volume from the equivalent medium for natural fractures, determining oil or gas reserves by calculating the fracture pore volume, and determining fracture porosity measurement from a test to calibrate 3D fracture models. The method also includes determining fracture porosity from a mechanical test, analyzing borehole image logs, developing a geomechanical model and fracture drivers, performing fracture model predictions, validating and calibrating the model, and determining fracture pore-volume of the core plug.