A method can include receiving porosimetry data for a range of pressures that spans a transition zone defined at least in part by a high-pressure end of a first pressure zone and a low-pressure end of a second pressure zone; detecting at least one artifact in the transition zone; computing accuracy information for the highpressure end of a first pressure zone and the low-pressure end of a second pressure zone; computing a pressure-volume adjustment based at least in part on the accuracy information; and outputting a pressure-volume relationship in the transition zone based at least in part on the pressure-volume adjustment.

A method of estimating a depth of a hydrocarbon-water contact of a hydrocarbon reservoir in a structure. The method may include the steps of analysing one or more samples obtained from the structure to generate a relationship relating resistivity to hydrocarbon-water contact depth, obtaining a resistivity measurement of the hydrocarbon reservoir, and estimating the hydrocarbon-water contact depth from the relationship relating resistivity to hydrocarbon-water contact depth and the resistivity measurement of the hydrocarbon reservoir.

A data processing method includes: collecting test data of a target rock sample in different gas adsorption experiments; the test data including pore sizes and pore volumes corresponding to the pore sizes and including at least two selected from the group consisting of the test data with pore sizes less than 3 nm in CO.sub.2 adsorption experiment, the test data with pore sizes in 1.5 nm to 250 nm in N.sub.2 adsorption experiment and the test data with pore sizes in 10 nm to 1000 μm in high-pressure mercury adsorption experiment; and fitting the test data in overlapping ranges of the pore sizes using a least square method, and obtaining target pore volumes corresponding to the pore sizes respectively. The accuracy of joint characterization of shale pore structures can be improved by using mathematical methods to process the data in overlapping ranges of pore sizes among different characterization methods.

A method includes screening heterogeneity of a rock sample using nuclear magnetic resonance testing to determine a composition of the rock sample, drilling at least one smaller rock sample representative of the determined composition, and testing the at least one smaller rock sample with mercury injection capillary pressure to obtain a capillary pressure distribution of the at least one smaller rock sample. The method further includes decomposing a T.sub.2 distribution from the nuclear magnetic resonance testing and the capillary pressure distribution using Gaussian fitting to identify multiple pore systems, where the small ends of the Gaussian fitted T.sub.2 distribution and the Gaussian fitted capillary pressure distribution are overlapped for at least one of the identified pore systems.

A single stage high pressure mercury injection capillary pressure measurement apparatus includes a sample sub-assembly, a transducer sub-assembly a hydraulic intensifier, and a gas cylinder. The sample sub-assembly includes a casing having walls defining an interior volume, a penetrometer arranged in the casing, the penetrometer having walls defining a sample volume, an annular space defined between the walls of the casing and the walls of the penetrometer, and a common chamber fluidly connected to the annular space by a fluid line and to the sample volume of the penetrometer by a tubing. The transducer sub-assembly is fluidly connected to the sample sub-assembly via the common chamber and includes a plurality of high-pressure transducers a plurality of low-pressure transducers. The hydraulic intensifier is fluidly connected to the common chamber and is configured to apply a high pressure to the annular space.

The effect of drilling fluids on particular subterranean environments can be analyzed to improve the formation of drilling fluids and additives such as lost circulation materials. A plug can be generated by a particle plugging apparatus by injecting lost circulation material into the particle plugging apparatus. A set of tests to be performed on the plug can be identified. The set of tests can include at least one physical test and at least one electronic test. A test schedule indicating the order in which each test of the set of tests is to be performed can be defined. The set of tests can be executed to generate a testing output. The testing output can be used to generate a three-dimensional network model of the plug.

A data processing method includes: collecting test data of a target rock sample in different gas adsorption experiments; the test data including pore sizes and pore volumes corresponding to the pore sizes and including at least two selected from the group consisting of the test data with pore sizes less than 3 nm in CO.sub.2 adsorption experiment, the test data with pore sizes in 1.5 nm to 250 nm in N.sub.2 adsorption experiment and the test data with pore sizes in 10 nm to 1000 μm in high-pressure mercury adsorption experiment; and fitting the test data in overlapping ranges of the pore sizes using a least square method, and obtaining target pore volumes corresponding to the pore sizes respectively. The accuracy of joint characterization of shale pore structures can be improved by using mathematical methods to process the data in overlapping ranges of pore sizes among different characterization methods.

A method includes screening heterogeneity of a rock sample using nuclear magnetic resonance testing to determine a composition of the rock sample, drilling at least one smaller rock sample representative of the determined composition, and testing the at least one smaller rock sample with mercury injection capillary pressure to obtain a capillary pressure distribution of the at least one smaller rock sample. The method further includes decomposing a T.sub.2 distribution from the nuclear magnetic resonance testing and the capillary pressure distribution using Gaussian fitting to identify multiple pore systems, where the small ends of the Gaussian fitted T.sub.2 distribution and the Gaussian fitted capillary pressure distribution are overlapped for at least one of the identified pore systems.

A method of rock typing includes obtaining mercury injection capillary pressure (MICP) data regarding a region of interest. A distance matrix is computed for distributions determined from the MICP data using a statistical distance metric. A cluster tree of the distributions is generated using the distance matrix. The cluster tree is adjusted based on a petrographic characteristic to produce an adjusted cluster tree, which is used to determine a pore structure types of the region of interest.

A method may comprise obtaining a formation sample, scanning the formation sample to form a data packet, loading the data packet on an information handling machine, performing a digital porous plate experiment with the data packet, and determining geometry of a pore throat in the formation sample. A system may comprise a computer tomographic machine configured to scan a formation sample and create a data packet from the scan and an information handling system. The information handling system may be configured to configured to perform a digital porous plate experiment with the data packet and determine geometry of a pore throat in the formation sample.