The invention relates to a calibration method for representing dense sandstone pore size distribution by adopting nuclear magnetic resonance; the method comprises the steps of measuring the rock porosity and the skeleton density; carrying out a low-temperature broken sample N2 absorption and desorption experiment, and carrying out a nuclear magnetic resonance test and a high pressure Hg injection test on a regular column sample in a saturated formation water state; converting pore volume obtained through N2 absorption into porosity components under different pore throat radiuses by using a capillary accumulated Hg inlet curve, and establishing a pore proportion summation curve by synthesizing low temperature N2-high pressure Hg injection; determining a best calibration coefficient by comparing the nuclear magnetic resonance pore proportion summation curves under the different C values to realize the conversion between nuclear magnetic resonance T2 spectrum and the pore throat radius; establishing a relation between parameters of the calibration coefficient C and a reflection pore-throat structure according to lithological characters; carrying out nuclear magnetic resonance conversion on dense sandstone reservoirs which are positioned in the same region and have the same lithological character. According to the method, the nuclear magnetic resonance T2 spectrum is calibrated by combining low temperature N2 absorption and a high pressure Hg injection experiment, and large pores, micropores and mesopores are calibrated, so that the distribution of different grades of pore sizes in dense sandstone can be effectively represented.

Calibration method for representing dense sandstone pore size distribution by adopting nuclear magnetic resonance

The invention relates to an evaluation method for reservoir distribution of a supergene karst of a carbonatite. The method comprises the following steps that features of the supergene karst are identified, a logging response standard for the supergene karst structure is established, the cyclicity of the supergene karst structure is divided, growth differences of different karst cyclicity are compared, and distribution benefit for the karst reservoir is evaluated. On the basis of analysis on geological and logging data, the karst cyclicity caused by change of the reference surface of karst in the supergene karst generating process is considered, and the multi-cyclicity of the supergene karst is divided and compared according to the geology observation and logging discrimination; and the cyclicity of the supergene karst and the discovered karst reservoir are analyzed in a combined manner to determine the karst cyclicity and vertical growth segments benefit for growth of the karst reservoir, the planar distribution of the corresponding karst cyclicity is used to determine planar distribution benefit for the karst reservoir, the disadvantages in evaluating the karst reservoir via the supergene karst structure are overcome, evaluation for the karst reservoir satisfies the practical geological evolution history more, the evaluation result is more accurate, and the success rate of exploration is effectively improved.

Evaluation method for distribution of supergene karst reservoir of carbonatite

The invention relates to the field of shale hydrocarbon reservoir exploration, and discloses a method for determining the pore structure through classifying the isothermal adsorption curve of mud shale The method comprises the following steps: 1, collecting the bedrock standard column sample of mud shale; 2, crushing the bedrock standard column sample obtained in step 1, carrying out isothermal adsorption test, and drafting an isothermal adsorption curve; 3, sorting the pore form, the pore size and the pore throat to obtain a mud shale isothermal adsorption curve standard map; and 4, comparing the isothermal adsorption curve of the detected sample with the mud shale isothermal adsorption curve standard map to obtain the pore structure of the detected sample The method for determining the pore structure through classifying the isothermal adsorption curve of mud shale realizes division of all types of isothermal adsorption curves of mud shale through the isothermal adsorption curve standard map standard map, and displays the difference of different isothermal adsorption curves; and the pore structure of the mud shale sample can be determined through the isothermal adsorption curve of the mud shale sample, and can be further associated with a shale gas exploitation apparatus

Method for determining pore structure through classifying isothermal adsorption curve of mud shale

The invention discloses a rock nano CT pore calibration method. The method comprises the following steps: manufacturing an SEM scanning region calibration belt and a CT scanning region calibration belt; carrying out SEM scanning on the top surface of a rock sample; carrying out CT scanning; calibrating an SEM scanning result pore; calibrating a pore threshold value Th of a CT top surface layer by using a pore calibrated by the SEM; and when the pore threshold value Th of the CT top surface layer, which is calibrated by the SEM, is obtained, calibrating other CT pore spaces by using the Th. According to the pore calibration method, SEM experiment data and a nano CT method are combined together, and the result of the nano CT is further calibrated by using the result of the SEM; and the CT data calibrated by an SEM high-precision picture has a clear pore space, and is the same as an SEM result obtained by a direct observation method.

Rock nano CT pore calibration method

The invention discloses a joint characterization method for pore size distribution of tight sandstone The method comprises the following steps: S1, performing a dry dehydration treatment on the tightsandstone; S2, performing an NMR test on core samples saturated with water; S3, performing high-pressure mercury intrusion analysis after the NMR test, and obtaining results of high-pressure mercuryintrusion pore size distribution by using a Washbum equation; S4, drilling a small core column for XCT experiment after drying and dewatering; S5, using the remaining core samples in the S4 after grinding, drying and dewatering for low-pressure nitrogen adsorption; S6, using the samples after low-pressure nitrogen adsorption in the S5 for carbon dioxide adsorption test after degassing; S7, fittingthe pore size distribution obtained by high-pressure mercury intrusion with NMR data to obtain conversion coefficients, wherein the T2 relaxation time distribution of NMR may be converted into a poresize; and S8, splicing and combining the measured data to obtain the pore size distribution of the tight sandstone The method can reasonably characterize the full pore size of the tight sandstone and ensure the objectivity of tight sandstone reservoir evaluation

Joint characterization method for pore size distribution of tight sandstone

The invention provides a method and a device for processing microcosmic pore throat data of tight sandstone, and relates to the technical field of representation of the microcosmic pore throat data of the tight sandstone. The method comprises the steps of representing pore throat structures of three Berea cores with the same porosity and permeability by a mercury penetration way, a carbon dioxide gas adsorption way and a nitrogen adsorption way, and generating a pore throat distribution function of the tight sandstone; acquiring the microcosmic pore throat data of the tight sandstone, and generating the distribution characteristic of the microcosmic pore throat data of the tight sandstone according to the pore throat distribution function of the tight sandstone and the microcosmic pore throat data of the tight sandstone. The microcosmic pore throat data of the tight sandstone is obtained by treating the tight sandstone in the real basin by the mercury penetration way, the carbon dioxide gas adsorption way and the nitrogen adsorption way. After the method and the device are adopted, the problem that in the prior art, various experimental methods are different in range of representation result for the microcosmic pore throat of the same tight reservoir, or are overlapped in range, so that the microcosmic pore throat size distribution characteristic of the tight reservoir is difficult to reflect can be solved.

Method and device for processing microcosmic pore throat data of tight sandstone

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Method and device for processing microcosmic pore throat data of tight sandstone