Method and device for obtaining core microscopic properties in displacement synergy scanning experiment

Abstract

The present application provides a method and device for obtaining the microscopic properties of a core in a displacement collaborative scanning experiment. The method includes: during the displacement collaborative scanning experiment on the core, in response to a core microscopic property acquisition instruction, obtaining a two-dimensional scanned image of the core, obtaining a three-dimensional image of the core by performing three-dimensional reconstruction on the two-dimensional scanned image, the three-dimensional image of the core including the three-dimensional structure of the porous medium of the core, obtaining the oil-gas ratio of the core according to the temperature, pressure applied in the displacement collaborative scanning experiment and the two-phase phase diagram of the core, and identifying the oil-gas two phases in the three-dimensional structure of the porous medium according to the oil-gas ratio of the core to obtain the three-dimensional spatial distribution of the oil and gas in the core, and the three-dimensional spatial distribution is used to guide oil and gas exploitation. Therefore, it is possible to accurately judge the distribution of the oil-gas two phases in the core and obtain the three-dimensional spatial distribution of the oil and gas.

Description

Technical Field

[0001] This application relates to the field of computer application technologies, and in particular, to a method and device for obtaining the microscopic properties of a core in a displacement collaborative scanning experiment. Background Art

[0002] Oil and gas resources are one of the most important basic resources in modern times. Currently, a large number of oil and gas reservoirs worldwide have entered the late stage of development, with increased development difficulty and reduced production efficiency. Therefore, the tapping of remaining oil and gas has always been a hot topic and a difficult point in the oil and gas industry.

[0003] Currently, experimental means have become the most representative technical method for tapping remaining oil and gas. Laboratory measurement technologies have developed various means such as sound, light, and electricity to measure the oil and gas saturation during the core oil displacement process. Among them, computer tomography technology has been widely used because it can relatively realistically microscopically visualize the three-dimensional structure of the core. However, due to the similar densities of oil and gas, it is impossible to distinguish oil and gas in the scanned image. Therefore, it is impossible to judge the oil-gas two-phase distribution in the pore structure of the core, and thus it is impossible to obtain the three-dimensional spatial distribution of oil and gas, resulting in a relatively low guiding effect on actual production. Summary of the Invention

[0004] This application provides a method and device for obtaining the microscopic properties of a core in a displacement collaborative scanning experiment to obtain the three-dimensional spatial distribution of oil and gas in the core and the microscopic occurrence state of oil and gas.

[0005] In a first aspect, this application provides a method for obtaining the microscopic properties of a core in a displacement collaborative scanning experiment, the method including:

[0006] During the displacement collaborative scanning experiment on the core, in response to a core microscopic property acquisition instruction, obtain a two-dimensional scanned image of the core.

[0007] Obtain a three-dimensional core image by performing three-dimensional reconstruction on the two-dimensional scanned image, where the three-dimensional core image includes the three-dimensional structure of the porous medium of the core.

[0008] According to the temperature, pressure applied in the displacement collaborative scanning experiment, and the two-phase phase diagram of the core, obtain the oil and gas proportion of the core, and identify the oil-gas two-phase in the three-dimensional structure of the porous medium according to the oil and gas proportion of the core to obtain the three-dimensional spatial distribution of oil and gas in the core, and the three-dimensional spatial distribution is used to guide oil and gas exploitation.

[0009] Optionally, identifying the oil-gas two-phase in the three-dimensional structure of the porous medium according to the oil and gas proportion of the core includes:

[0010] Locate the distribution of oil and gas in the three-dimensional core image according to the radiation attenuation change indicated by the pixel points in the three-dimensional core image; identify the oil-gas two-phase in the three-dimensional structure of the porous medium according to the distribution of oil and gas in the three-dimensional core image and the oil and gas proportion of the core.

[0011] Optionally, locating the distribution of oil and gas in the three-dimensional core image according to the radiation attenuation change indicated by the pixel points in the three-dimensional core image includes:

[0012] Obtaining the attenuation coefficient of the pixel points corresponding to the oil and gas in the three-dimensional core image; locating the distribution of oil and gas in the three-dimensional core image according to the radiation attenuation change indicated by the pixel points in the three-dimensional core image and the attenuation coefficient of the pixel points corresponding to the oil and gas.

[0013] Optionally, the method for obtaining the microscopic properties of the core in the displacement collaborative scanning experiment further includes:

[0014] Obtaining quantitative description information on the occurrence state of oil and gas in the three-dimensional structure of the porous medium according to the three-dimensional spatial distribution of the oil and gas in the core; obtaining the occurrence state of the oil and gas in the three-dimensional structure of the porous medium according to the quantitative description information on the occurrence state.

[0015] Optionally, the quantitative description information on the occurrence state includes the shape factor and / or the contact surface area ratio. Obtaining the quantitative description information on the occurrence state of the oil and gas in the three-dimensional structure of the porous medium according to the three-dimensional spatial distribution of the oil and gas in the core includes:

[0016] Obtaining the volume and surface area of the oil and gas according to the shape of the oil and gas in the three-dimensional structure of the porous medium in the core; obtaining the shape factor of the oil and gas in the three-dimensional structure of the porous medium according to the volume and surface area of the oil and gas; and / or, obtaining the contact area between the oil and gas and the pores according to the distribution and proportion of the oil and gas in the core; obtaining the contact surface area ratio of the oil and gas in the three-dimensional structure of the porous medium according to the surface area of the oil and gas and the contact area between the oil and gas and the pores.

[0017] Optionally, the quantitative description information on the occurrence state of the oil and gas includes the quantitative description information on the occurrence state of multiple oil and gas blocks. Obtaining the occurrence state of the oil and gas in the three-dimensional structure of the porous medium according to the quantitative description information on the occurrence state includes:

[0018] Determining the set judgment conditions satisfied by the quantitative description information on the occurrence state according to the quantitative description information on the occurrence state of each oil and gas block; obtaining the occurrence state of the oil and gas block according to the correlation between the set judgment conditions and the occurrence state of the oil and gas.

[0019] In a second aspect, the present application provides a device for obtaining the microscopic properties of a core in a displacement collaborative scanning experiment. The device includes:

[0020] An acquisition module, configured to obtain a two-dimensional scanned image of the core in response to a core microscopic property acquisition instruction during the displacement collaborative scanning experiment on the core.

[0021] A reconstruction module for obtaining a three-dimensional core image through three-dimensional reconstruction of a two-dimensional scanned image, where the three-dimensional core image includes the three-dimensional structure of the porous medium of the core.

[0022] A processing module for obtaining the oil-gas ratio of the core according to the temperature, pressure applied in the displacement co-scanning experiment, and the two-phase phase diagram of the core, and identifying the oil-gas two-phase in the three-dimensional porous medium structure according to the oil-gas ratio of the core to obtain the three-dimensional spatial distribution of the oil and gas in the core, and the three-dimensional spatial distribution is used to guide oil and gas exploitation.

[0023] Optionally, the processing module is specifically used for:

[0024] Locate the distribution of oil and gas in the three-dimensional core image according to the change in radiation attenuation indicated by the pixel points in the three-dimensional core image;

[0025] Identify the oil-gas two-phase in the three-dimensional porous medium structure according to the distribution of oil and gas in the three-dimensional core image and the oil-gas ratio of the core.

[0026] Optionally, the processing module is specifically used for:

[0027] Obtain the attenuation coefficient of the pixel points corresponding to the oil and gas in the three-dimensional core image;

[0028] Locate the distribution of oil and gas in the three-dimensional core image according to the change in radiation attenuation indicated by the pixel points in the three-dimensional core image and the attenuation coefficient of the pixel points corresponding to the oil and gas.

[0029] Optionally, the processing module is also used for:

[0030] Obtain quantitative description information on the occurrence state of oil and gas in the three-dimensional porous medium structure according to the three-dimensional spatial distribution of the oil and gas in the core; and obtain the occurrence state of the oil and gas in the three-dimensional porous medium structure according to the quantitative description information on the occurrence state.

[0031] Optionally, the quantitative description information on the occurrence state of oil and gas includes a shape factor and / or a contact surface area ratio. The processing module is specifically used for:

[0032] Obtain the volume and surface area of the oil and gas according to the shape of the oil and gas in the three-dimensional porous medium structure of the core; obtain the shape factor of the oil and gas in the three-dimensional porous medium structure according to the volume and surface area of the oil and gas; and / or, obtain the contact area between the oil and gas and the pores according to the distribution of the oil and gas in the core and the oil-gas ratio; obtain the contact surface area ratio of the oil and gas in the three-dimensional porous medium structure according to the surface area of the oil and gas and the contact area between the oil and gas and the pores.

[0033] Optionally, the quantitative description information on the occurrence state of oil and gas includes the quantitative description information on the occurrence state of multiple oil and gas blocks. The processing module is specifically used for:

[0034] Determine the set of judgment conditions satisfied by the quantitative description information of the occurrence state according to the quantitative description information of the occurrence state of each oil and gas block; obtain the occurrence state of the oil and gas block according to the correlation between the set judgment conditions and the oil and gas occurrence state.

[0035] In a third aspect, the present application provides an electronic device, including:

[0036] A processor; and

[0037] A memory for storing executable instructions of the processor;

[0038] Wherein, the processor is configured to execute the method for obtaining the microscopic properties of the core in the displacement collaborative scanning experiment as described in the first aspect of the present application by executing the executable instructions.

[0039] In a fourth aspect, the present application provides a computer-readable storage medium, on which a computer program is stored, and when the computer program is executed by a processor, the method for obtaining the microscopic properties of the core in the displacement collaborative scanning experiment as described in the first aspect of the present application is implemented.

[0040] In a fifth aspect, the present application provides a computer program product, including a computer program, and when the computer program is executed by a processor, the method for obtaining the microscopic properties of the core in the displacement collaborative scanning experiment as described in the first aspect of the present application is implemented.

[0041] The method and device for obtaining the microscopic properties of the core in the displacement collaborative scanning experiment provided by the present application, during the process of performing the displacement collaborative scanning experiment on the core, in response to the core microscopic property acquisition instruction, obtain a two-dimensional scanned image of the core, obtain a three-dimensional core image by performing three-dimensional reconstruction on the two-dimensional scanned image, the three-dimensional core image includes the three-dimensional structure of the porous medium of the core, obtain the oil and gas occupancy ratio of the core according to the temperature, pressure applied in the displacement collaborative scanning experiment and the two-phase phase diagram of the core, and identify the oil and gas two phases in the three-dimensional structure of the porous medium according to the oil and gas occupancy ratio of the core, obtain the three-dimensional spatial distribution of the oil and gas in the core, and the three-dimensional spatial distribution is used to guide oil and gas exploitation. Since the present application combines the reconstruction of the three-dimensional core image with the current oil and gas occupancy ratio to identify the oil and gas two phases in the three-dimensional core image, and then obtain the three-dimensional spatial distribution of the oil and gas in the core, therefore, it can accurately judge the distribution of the oil and gas two phases in the core, obtain the three-dimensional spatial distribution of the oil and gas, and researchers can specifically evaluate the oil and gas exploitation plan according to the three-dimensional spatial distribution of the oil and gas in the three-dimensional porous medium image during the process of performing experiments on the core, which has extremely high guiding significance for the actual oil and gas exploitation process. Description of the Drawings

[0042] To more clearly illustrate the technical solutions in the embodiments of the present application or the prior art, the following will briefly introduce the accompanying drawings required for the description of the embodiments or the prior art. Obviously, the accompanying drawings in the following description are some embodiments of the present application. For those of ordinary skill in the art, without creative efforts, other drawings can also be obtained based on these drawings.

[0043] Figure 1 Schematic diagram of an application scenario provided by an embodiment of the present application;

[0044] Figure 2 Flowchart of a method for obtaining the microscopic properties of a core in a displacement collaborative scanning experiment provided by an embodiment of the present application;

[0045] Figure 3 For another embodiment of the present application, Figure 2 Flowchart for detailed description of step 230 in the illustrated embodiment;

[0046] Figure 4 For another embodiment of the present application, Figure 3 Flowchart for detailed description of step 231 in the illustrated embodiment;

[0047] Figure 5 Flowchart of a method for obtaining the microscopic properties of a core in a displacement collaborative scanning experiment provided by another embodiment of the present application;

[0048] Figure 6 Flowchart for obtaining the shape factor of oil and gas based on the three-dimensional spatial distribution of oil and gas in a core provided by another embodiment of the present application;

[0049] Figure 7 Flowchart for obtaining the contact surface area ratio of oil and gas based on the three-dimensional spatial distribution of oil and gas in a core provided by another embodiment of the present application;

[0050] Figure 8 For another embodiment of the present application, Figure 5 Flowchart for detailed description of step 250 in the illustrated embodiment;

[0051] Figure 9 Schematic structural diagram of a device for obtaining the microscopic properties of a core in a displacement collaborative scanning experiment provided by an embodiment of the present application;

[0052] Figure 10 Schematic structural diagram of an electronic device provided by an embodiment of the present application. Detailed implementation manners

[0053] To make the objectives, technical solutions, and advantages of the embodiments of this application clearer, the following will clearly and completely describe the technical solutions in the embodiments of this application with reference to the accompanying drawings in the embodiments of this application. Obviously, the described embodiments are some, but not all, of the embodiments of this application. All other embodiments obtained by those of ordinary skill in the art based on the embodiments in this application without creative efforts shall fall within the scope of protection of this application.

[0054] The tapping of remaining oil and gas in oil and gas reservoirs has always been a hot topic and a difficult point in the oil and gas industry. Currently, experimental means have become the most representative technical method for tapping remaining oil and gas. In laboratory measurement technology, various means such as sound, light, and electricity are developed to measure the oil and gas saturation during the core flooding process. Among them, computed tomography technology is widely used because it can relatively truly microscopically visualize the three-dimensional structure of the core. However, due to the similar densities of oil and gas, it is impossible to distinguish oil and gas in the scanned images. Therefore, it is impossible to judge the two-phase distribution of oil and gas in the pore structure of the core, and thus impossible to obtain the three-dimensional distribution of oil and gas, resulting in a low guiding effect on actual production.

[0055] Therefore, this application provides a method and device for obtaining the microscopic properties of a core in a displacement collaborative scanning experiment. During the displacement collaborative scanning experiment on the core, three-dimensional reconstruction of the core is performed to obtain a three-dimensional core image containing the three-dimensional structure of the porous medium of the core. Based on this three-dimensional core image and the temperature and pressure applied in the displacement collaborative scanning experiment, oil and gas two phases are identified in the three-dimensional structure of the porous medium, and then the three-dimensional spatial distribution of oil and gas in the core is obtained to guide oil and gas exploitation.

[0056] Figure 1 It is a schematic diagram of an application scenario provided by an embodiment of this application. As Figure 1 shown, this application scenario includes an experimental device 110, an imaging device 120, and a computer device 130.

[0057] Among them, the experimental device 110 is used to perform a displacement collaborative experiment on the core under the natural environment simulating the oil and gas reservoir formation corresponding to the core, using a specific exploitation plan (such as gas injection and water injection exploitation plans), so as to simulate the real oil production process in the oil and gas reservoir formation. Thus, the oil and gas distribution situation of the core in the experiment corresponds to the real oil production process, and then the real oil production process can be guided based on the experimental results.

[0058] The imaging device 120 is a computed tomography (CT) device, which is used to perform CT scans on the core during the displacement collaborative experiment on the core and generate a series of two-dimensional scan images.

[0059] The computer device 130 obtains a series of two-dimensional scanned images of the core from the imaging device 120, performs three-dimensional reconstruction on the series of two-dimensional scanned images to obtain a three-dimensional core image, and accurately realizes the display of the three-dimensional spatial distribution of oil and gas in the core in the three-dimensional core. Based on the change in the three-dimensional spatial distribution of oil and gas in the core during the displacement cooperation experiment, the true state of oil and gas development is inferred, which helps to analyze the oil and gas distribution state in the oilfield, provides targeted guidance and selection for the development plan of remaining oil and gas, and improves the oil and gas recovery efficiency.

[0060] The specific implementation process of obtaining the microscopic properties of the core in the displacement cooperation scanning experiment can refer to the solutions of the following embodiments. It should be noted that the application scenarios of the solutions of this application are not limited to Figure 1 as shown.

[0061] Figure 2 FIG. is a flowchart of a method for obtaining the microscopic properties of a core in a displacement cooperation scanning experiment provided by an embodiment of this application. The method of this embodiment can be specifically executed by the computer device 130 in the Figure 1 application scenario as shown. As Figure 2 shown, the method of this embodiment at least includes the following steps:

[0062] Step 210, during the displacement cooperation scanning experiment on the core, in response to the core microscopic property acquisition instruction, obtain the two-dimensional scanned image of the core.

[0063] Among them, the core is a reservoir rock sample of an oil reservoir used for the displacement cooperation scanning experiment, and the oil and gas distribution and state in the core correspond to the oil and gas distribution and state in the oil reservoir. The core microscopic property acquisition instruction can be input by the user to the electronic device executing the embodiment of this method, or sent by other devices to the electronic device executing the embodiment of this method.

[0064] The displacement cooperation scanning experiment on the core refers to simulating the natural environment of the oil reservoir corresponding to the core, using a specific exploitation scheme (such as gas injection and water injection exploitation schemes) to exploit the oil and gas in the core, and using an imaging device to scan the core during the oil and gas exploitation process to obtain the two-dimensional scanned image of the core. It should be understood that the two-dimensional scanned image of the core is not a single image, but a set of images obtained by scanning according to a set of scanning profiles.

[0065] Specifically, using an imaging device, such as a CT scanner, scan the core according to the set scanning profile in the imaging plane of the core, respectively obtain a corresponding set of projection data, use these projection data to inversely calculate the attenuation coefficient of each pixel point on the imaging plane, and reconstruct the two-dimensional image section, that is, the two-dimensional scanned image, from the attenuation coefficient of the pixel points. Thus, the two-dimensional scanned image of the core reflects the two-dimensional existence form of the core cross-section.

[0066] It should be further noted that the CT scanner used can be a micro-CT imaging device. For a scanning section, the X-rays emitted by the micro-CT imaging device pass through the core, and each part of the core has a different absorption rate for X-rays. The X-ray source, that is, the micro-CT imaging device, emits X-rays, penetrates the core, and finally projects an image on the X-ray detector in the micro-CT imaging device to obtain the set of projection data mentioned above.

[0067] And so on, for each set of projection data, two-dimensional reconstruction is performed to obtain a two-dimensional scanned image, and then a set of two-dimensional scanned images of the core is obtained.

[0068] Step 220, obtain a three-dimensional core image by performing three-dimensional reconstruction on the two-dimensional scanned image. The three-dimensional core image includes the three-dimensional structure of the porous medium of the core.

[0069] Among them, the so-called three-dimensional core image is an image that constructs a three-dimensional space through two-dimensional scanned images and reconstructs the three-dimensional structure of the porous medium of the core in this three-dimensional space. The three-dimensional core image is used to realize the spatial distribution of the core and the substances existing therein. For example, an accurate description of the existing pores and skeletons. It should be understood that a porous medium is a common space occupied by multi-phase substances. For a core, the porous medium includes pores and skeletons. Specifically, the so-called skeleton corresponds to the solid phase of the core, and the so-called pores mainly include the liquids (such as oil or water) and gases (such as natural gas or air) existing in the core.

[0070] Through the three-dimensional core image obtained by three-dimensional reconstruction, the three-dimensional distribution of the core and the three-dimensional distribution of the liquid phase existing in the core on this basis are obtained, thereby forming a display of the three-dimensional structure of the porous medium of the core.

[0071] It should be supplemented here that the so-called three-dimensional reconstruction is achieved through the superposition of a series of two-dimensional scanned images. And through the display of the three-dimensional structure of the porous medium of the core, relevant researchers can read the porous medium parameters of the core, such as the porosity of the core and the pore throat size distribution, which is beneficial for relevant researchers to conduct multi-dimensional analysis of the oil and gas in the core. For example, calculate the oil and gas saturation according to the number of voxels occupied by the oil and gas in the three-dimensional image.

[0072] It should be noted that whether it is a two-dimensional scanned image or a three-dimensional core image, they are both arrangements of pixel points. The magnitude of the attenuation coefficient corresponding to each pixel point represents the pixel value of this pixel point, and a corresponding grayscale image, such as a three-dimensional grayscale image, is also obtained from this pixel value.

[0073] A three-dimensional gray-scale image is obtained by converting the three-dimensional core image. For the three-dimensional gray-scale image, binary processing is applied. For example, the watershed calculation method in the binary processing method is used to segment and identify pores and skeletons, and a corresponding binary three-dimensional model is obtained, so as to obtain the three-dimensional structure of the porous medium of the core, that is, the three-dimensional structure of pores and skeletons in three-dimensional space.

[0074] So far, the accurate description and characterization of the three-dimensional structure of the core have been realized, and on this basis, the subsequent analysis of oil and gas in the core can be realized.

[0075] For the binary processing of the three-dimensional gray-scale image, it should be understood that the gray-scale value corresponding to the pixel point in the three-dimensional gray-scale image reflects the strength of the absorption of X-rays by the corresponding component at the corresponding position. The larger the gray-scale, the higher the height, which represents the skeleton; on the contrary, the smaller the gray-scale, the darker the brightness, which represents the existence of pores in three-dimensional space. Therefore, the skeleton and pores can be segmented and identified by the binary method.

[0076] Step 230: According to the temperature, pressure applied in the displacement collaborative scanning experiment and the two-phase phase diagram of the core, obtain the oil-gas ratio of the core, and identify the oil-gas two phases in the three-dimensional structure of the porous medium according to the oil-gas ratio of the core, and obtain the three-dimensional spatial distribution of oil and gas in the core. The three-dimensional spatial distribution is used to guide oil and gas exploitation.

[0077] Among them, after obtaining the three-dimensional image of the core and the three-dimensional structure of the porous medium of the core, the oil-gas two phases in the three-dimensional structure of the porous medium can be identified on this basis in combination with the oil-gas ratio of the core, and then the oil and gas in the core can be analyzed. It should be understood that the oil-gas ratio of the core refers to the ratio of the volumes of the two phases of crude oil and natural gas in the core.

[0078] Specifically, the oil-gas ratio can be obtained through the two-phase phase diagram of oil and gas. This two-phase phase diagram is the pressure-volume-temperature (PVT) relationship diagram corresponding to oil and gas. For example, the abscissa in this two-phase relationship diagram can be temperature, the ordinate can be pressure, and the curves in the diagram can represent the oil-gas volumes under different oil-gas ratios. This two-phase phase diagram can be obtained through PVT experiments, specifically by measuring the oil-gas ratio of oil-gas samples at different temperatures and pressures, where the oil-gas samples are obtained by sampling the produced oil and gas during the production process.

[0079] Therefore, according to the temperature and pressure used in the displacement collaborative scanning experiment on the core, the oil-gas ratio of the core can be found accordingly from the two-phase phase diagram of oil and gas.

[0080] Through the pixel points in the three-dimensional image of the core, the corresponding attenuation coefficients can be obtained. Both oil / gas and rock components have corresponding attenuation coefficients, that is, the X-rays absorbed by oil / gas and rock components are different. Therefore, the three-dimensional distribution of oil / gas can be obtained in the three-dimensional structure of the porous medium of the core through the radiation attenuation changes corresponding to the pixel points in the three-dimensional image of the core, that is, the three-dimensional distribution of oil / gas that constitutes the pores.

[0081] Based on the oil / gas ratio in the core and the three-dimensional structure of the porous medium, methods such as the Gaussian function can be used to identify the oil / gas two-phase in the three-dimensional structure of the porous medium, and then the three-dimensional spatial distributions of oil and gas can be obtained, so as to accurately display the three-dimensional spatial distribution of oil / gas in the three-dimensional structure of the porous medium. It should be understood that the three-dimensional spatial distribution of oil / gas can distinguish the three-dimensional spatial distribution of oil and the three-dimensional spatial distribution of gas.

[0082] The method for obtaining the microscopic properties of the core in the displacement collaborative scanning experiment provided by this application, during the displacement collaborative scanning experiment on the core, in response to the instruction for obtaining the microscopic properties of the core, a two-dimensional scanned image of the core is obtained, and a three-dimensional image of the core is obtained by three-dimensional reconstruction of the two-dimensional scanned image. The three-dimensional image of the core includes the three-dimensional structure of the porous medium of the core. According to the temperature, pressure applied in the displacement collaborative scanning experiment and the two-phase phase diagram of the core, the oil / gas ratio of the core is obtained, and the oil / gas two-phase is identified in the three-dimensional structure of the porous medium according to the oil / gas ratio of the core, and the three-dimensional spatial distribution of oil / gas in the core is obtained. The three-dimensional spatial distribution is used to guide oil / gas exploitation. Since this application combines the reconstruction of the three-dimensional image of the core with the current oil / gas ratio to identify the oil / gas two-phase in the three-dimensional image of the core, and then obtain the three-dimensional spatial distribution of oil / gas in the core, therefore, the distribution of the oil / gas two-phase in the core can be accurately judged, the three-dimensional spatial distribution of oil / gas can be obtained, and researchers can specifically evaluate the oil / gas exploitation plan according to the three-dimensional spatial distribution of oil / gas in the three-dimensional image of the porous medium during the experiment on the core, which has extremely high guiding significance for the actual oil / gas exploitation process.

[0083] Figure 3 For another embodiment of this application Figure 2 The flowchart for detailed description of step 230 in the shown embodiment. In an exemplary embodiment, as Figure 3 shown, step 230 at least includes the following steps:

[0084] Step 231, locate the distribution of oil / gas in the three-dimensional image of the core according to the radiation attenuation changes indicated by the pixel points in the three-dimensional image of the core.

[0085] Among them, the skeleton and pore parts in the core are determined by CT scanning, and on this basis, the distribution of oil / gas in the core is obtained.

[0086] For example, through the presence of pixel points in the three-dimensional image of the core, the pores and throats where the oil and gas are located can be determined. Based on this, through the principle of radiation attenuation, i.e., Beer's law, using the formula I = I0e -μx to perform calculation and analysis to obtain the attenuation coefficient of each pixel point in the three-dimensional image of the core. In this formula I = I0e -μx , I0 represents the radiation intensity when the X-ray is incident on the core surface; I represents the X-ray radiation intensity corresponding to a certain point after the X-ray passes through the material layer due to absorption and scattering; μ is the attenuation coefficient, which represents the percentage value of the intensity reduction when the X-ray passes through a unit thickness of the material layer (a property unique to different materials), and the unit is m -1 ; x is the thickness of the material layer, and the unit is m.

[0087] For the three-dimensional image of the core, according to the attenuation coefficients corresponding to the oil and gas parts and the rock part, the attenuation coefficient corresponding to the pixel points in the three-dimensional image of the core is compared with the attenuation coefficients corresponding to the oil and gas parts and the rock part, so as to obtain the three-dimensional distribution of the oil and gas on the three-dimensional structure of the porous medium.

[0088] Step 232, identify the oil-gas two-phase in the three-dimensional structure of the porous medium according to the distribution of the oil and gas in the three-dimensional image of the core and the oil and gas proportion of the core.

[0089] Among them, according to the distribution of the oil and gas in the three-dimensional image of the core and the oil and gas proportion corresponding to the core pressure and temperature, the oil and gas two-phase in the three-dimensional structure of the porous medium of the core can be specifically identified.

[0090] Although the densities of oil and gas are similar, there are slight differences in their attenuation coefficients. Therefore, after obtaining the attenuation coefficients corresponding to the pixel points of the oil and gas parts in the three-dimensional core, based on the obtained oil and gas proportion, methods such as Gaussian simulation can be used for simulation calculation to calculate the proportion and position of the pixel points corresponding to oil and gas according to the proportion of the oil and gas proportion, and then identify the oil-gas two-phase in the three-dimensional structure of the porous medium. Specifically, first normalize the attenuation coefficient of each pixel point from large to small, then set the minimum value to 0, the maximum value to 65535, and the intermediate value changes accordingly, so as to complete the transformation from the attenuation coefficient to the gray value, and then use methods such as Gaussian simulation for gray value division. The signals of the oil and gas two-phase are relatively close, and it is necessary to divide according to the percentage in the pore structure with known oil and gas content. For example, oil accounts for 10% and gas accounts for 90%. Generally speaking, the gray value of oil is still higher than that of gas phase, so the 10% part with higher gray value in the pores is classified as oil, and the rest is the gas phase, and record the gray value basis for the division at this time. Then change the proportion of the oil and gas content, and use the same method to obtain the gray value basis for threshold division. After carrying out multiple tests in this way, a relatively stable and reliable division gray value basis can be obtained, and then the oil and gas two-phase in the three-dimensional image of the core obtained from the subsequent experiment can be divided.

[0091] Thus, after locating the distribution of oil and gas in the three-dimensional core image in this embodiment, by according to the distribution of oil and gas in the three-dimensional core image and the oil and gas proportion of the core, the oil-gas two-phase in the three-dimensional structure of the porous medium is further identified. During the displacement cooperation experiment on the core, the three-dimensional spatial distribution change of oil and gas can be simulated and displayed in the three-dimensional structure of the porous medium, so that the oil production scheme adopted in the experiment can be evaluated according to the three-dimensional spatial distribution change of oil and gas.

[0092] Figure 4 For another embodiment of the present application, it is a Figure 3 flowchart for detailing step 231 in the illustrated embodiment. In an exemplary embodiment, as Figure 4 shown, step 231 at least includes the following steps:

[0093] Step 301, obtain the attenuation coefficient of the pixel points corresponding to oil and gas in the three-dimensional core image.

[0094] Step 302, locate the distribution of oil and gas in the three-dimensional core image according to the radiation attenuation change indicated by the pixel points in the three-dimensional core image and the attenuation coefficient of the pixel points corresponding to oil and gas.

[0095] Among them, the attenuation coefficient of oil and gas has independent characteristics, and the three-dimensional data volume corresponding to the three-dimensional core image is composed of grayscale value images. Specifically, when X-rays pass through a pixel block (i.e., the pixel point of the three-dimensional core image), the ray intensity value decreases from I0 to I1. Then, according to the above formula I = I0e -μx , the attenuation coefficient corresponding to this pixel block can be obtained as (I0 - I1) / x. After obtaining the attenuation coefficient of the pixel block corresponding to oil and gas in the three-dimensional core image, normalize the attenuation coefficient of each pixel block from large to small, then set the minimum value to 0, the maximum value to 65535, and the intermediate values change accordingly, so as to complete the conversion from the attenuation coefficient of each pixel block to the grayscale value of each pixel block. After obtaining the grayscale value of each pixel block, perform grayscale value division to obtain whether there is oil and gas in this pixel block. By analogy, the three-dimensional distribution of oil and gas in the entire three-dimensional space can be obtained and accurately located. The grayscale value division is specifically as follows: The oil and gas rock needs to be calibrated first. The grayscale value difference between oil and gas and rock is relatively large, and a suitable threshold can be directly selected for grayscale value division.

[0096] Thus, this embodiment obtains the distribution of oil and gas by obtaining the attenuation coefficient of the pixel points corresponding to oil and gas in the three-dimensional core image, converting the attenuation coefficient into the corresponding grayscale value, and performing grayscale value division. Based on this, the three-dimensional distribution of oil and gas in the three-dimensional structure of the core porous medium is determined.

[0097] Figure 5A flow chart of a method for obtaining core microscopic properties in a displacement cooperative scanning experiment provided in another embodiment of the present application. In an exemplary embodiment, Figure 5 As shown, after step 230, the method for obtaining core microscopic properties in the displacement coordinated scanning experiment further includes the following steps:

[0098] Step 240, based on the three-dimensional spatial distribution of oil and gas in the core, obtain quantitative description information of the occurrence state of oil and gas in the three-dimensional structure of the porous medium.

[0099] Step 250, obtaining the occurrence state of oil and gas in the three-dimensional structure of the porous medium according to the occurrence state quantitative description information.

[0100] The occurrence state of oil and gas refers to the physical state of the oil and gas, specifically, the physical state of each unconnected oil and gas block in the core.

[0101] In determining this occurrence state, it is first necessary to define different occurrence states in order to set the judgment conditions corresponding to various occurrence states, so as to lay the foundation for the subsequent acquisition of the oil and gas occurrence state.

[0102] The calculation of the oil and gas occurrence state refers to the statistics of information related to each location in the three-dimensional structure of the porous medium where the oil and gas are located, so as to calculate the quantitative description information of the occurrence state that can quantitatively describe the oil and gas occurrence state in three-dimensional space.

[0103] As described above, the judgment conditions corresponding to the different occurrence states of oil and gas are pre-configured. Therefore, after obtaining the quantitative description information of the occurrence state, the occurrence state of oil and gas in the three-dimensional structure of the porous medium of the core can be finally obtained by comparing the judgment conditions.

[0104] It should be noted that in the core, the occurrence states of oil and gas are mainly divided into: oil film, solitary particles, network and porous forms.

[0105] In one embodiment, the quantitative description information of the occurrence state includes a shape factor, which represents the regularity of the shape of the oil and gas (for example, the spherical shape factor is the largest and equal to 1), and is used to describe the surface area and shape of the oil and gas under the same volume.

[0106] The smaller the shape factor, the larger the surface area of ​​the oil and gas under the same volume, the greater the degree of surface unevenness, and the more irregular its shape. Through the shape factor, the quantitative description of the occurrence state of oil and gas is mapped to the same numerical space, so that the corresponding occurrence state can be determined at the same scale.

[0107] Figure 6The flowchart for obtaining the shape factor of oil and gas based on the three-dimensional spatial distribution of oil and gas in a core provided by another embodiment of the present application. As Figure 6 shown, in an exemplary embodiment, the process of obtaining the shape factor of oil and gas based on the three-dimensional spatial distribution of oil and gas in a core may include the following steps:

[0108] Step 411: Obtain the volume and surface area of the oil and gas according to the shape of the oil and gas in the three-dimensional structure of the porous medium in the core.

[0109] Step 412: Obtain the shape factor of the oil and gas in the three-dimensional structure of the porous medium according to the volume and surface area of the oil and gas.

[0110] Among them, for the oil and gas blocks distributed throughout the core, their volume and surface area can be obtained accordingly according to their shape in the three-dimensional structure of the porous medium.

[0111] The shape factor can be specifically obtained through the following formula (1):

[0112]

[0113] where G is the shape factor, V is the volume of the oil and gas, and S is the surface area of the oil and gas.

[0114] In another embodiment, the quantitative description information of the occurrence state further includes the contact surface area ratio. The contact surface area ratio refers to the ratio of the contact area to the surface area of the oil and gas block, which reflects the relative position relationship between the oil and gas and the pore surface. The larger the contact surface area ratio, the closer the oil and gas distribution is to the core matrix.

[0115] Figure 7 The flowchart for obtaining the contact surface area ratio of oil and gas based on the three-dimensional spatial distribution of oil and gas in a core provided by another embodiment of the present application. As Figure 7 shown, in an exemplary embodiment, the process of obtaining the contact surface area ratio of oil and gas based on the three-dimensional spatial distribution of oil and gas in a core may include the following steps:

[0116] Step 413: Obtain the contact area between the oil and gas and the pores according to the oil and gas distribution and the oil and gas proportion in the core.

[0117] Step 414: Obtain the contact surface area ratio of the oil and gas in the three-dimensional structure of the porous medium according to the surface area of the oil and gas and the contact area between the oil and gas and the pores.

[0118] Among them, the oil and gas are usually contained in the pore space formed by the core skeleton. Taking the core skeleton as the core matrix, the contact area between the oil and gas and the pores is actually the contact area between the oil and gas and the core matrix.

[0119] Based on the three-dimensional distribution of oil and gas and the proportion of oil and gas, the contact area between each oil and gas block in the core and the core matrix can be obtained, as well as the surface area of the oil and gas block. The contact surface area ratio is calculated from the obtained contact area and the surface area of the oil and gas block, and then the occurrence state of the corresponding oil and gas block is quantitatively described by the contact surface area ratio.

[0120] Specifically, the above contact surface area ratio can be obtained through the following formula two:

[0121]

[0122] Among them, S c represents the contact area, S represents the surface area of the oil and gas block itself, and R c represents the contact surface area ratio of the oil and gas block.

[0123] Through the above method, through the shape factor and the contact surface area ratio, the quantitative description of the occurrence state of oil and gas in the core is reflected as a whole and in the relevant relationship with the core matrix, laying a foundation for determining the occurrence state of oil and gas subsequently.

[0124] Figure 8 This is a flowchart for detailed description of step 250 in another embodiment of the present application. In an exemplary embodiment, the quantitative description information of the occurrence state of oil and gas includes the quantitative description information of the occurrence state of multiple oil and gas blocks. As Figure 5 shown, step 250 at least includes the following steps: Figure 8 shown, step 250 at least includes the following steps:

[0125] Step 251, according to the quantitative description information of the occurrence state of each oil and gas block, determine the set judgment conditions satisfied by the quantitative description information of the occurrence state.

[0126] Step 252, according to the correlation between the set judgment conditions and the occurrence state of oil and gas, obtain the occurrence state of the oil and gas block.

[0127] Among them, for each oil and gas block, the obtained quantitative description information of the occurrence state is compared with the set judgment conditions to obtain the judgment conditions that match the quantitative description information of its own occurrence state.

[0128] The so-called judgment conditions are corresponding to the occurrence state of the oil and gas block. Therefore, after finding the judgment conditions that the oil and gas block conforms to, the occurrence state of the oil and gas block can be obtained from the corresponding occurrence state of the oil and gas.

[0129] In a specific implementation of an exemplary embodiment, for the occurrence states of mineral components, they can be classified into flaky, solitary granular, network-like, porous, etc. Thus, corresponding judgment conditions can be set respectively for this. Table 1 shows the occurrence states of oil and gas and their judgment conditions. As shown in Table 1, where 0 < c < b < a < 1, 0 < e < f < g < d < 1, G is the shape factor, and R c is the contact surface area ratio.

[0130] Table 1 Occurrence States of Oil and Gas and Their Judgment Conditions

[0131]

[0132] Thus, through the implementation of this exemplary embodiment, an accurate description of the occurrence state of oil and gas blocks in the porous medium can be achieved in the three-dimensional structure of the porous medium of the presented core, and further, a description of the overall occurrence state of oil and gas in the core can be obtained.

[0133] In an exemplary embodiment, after step 230, the method for obtaining the microscopic properties of the core in the displacement collaborative scanning experiment at least includes the following steps:

[0134] Simulate the migration and distribution of oil and gas in three-dimensional space during the oil and gas production process through the displacement collaborative scanning experiment.

[0135] Among them, in the displacement collaborative scanning experiment, different oil production methods are simulated to extract oil and gas, and the distribution and migration changes of oil and gas in the three-dimensional structure of the porous medium of the core are observed.

[0136] Specifically, at different reservoir temperatures and pressures, displacement experiments are carried out using different oil production methods such as depletion, gas injection, or water injection. During the experiment, the three-dimensional distribution of oil and gas in the pore structure of the core is obtained through the above steps 210 to 230, and the migration conditions of oil and gas are observed through the changes in the three-dimensional distribution.

[0137] Figure 9 This is a schematic structural diagram of the device for obtaining the microscopic properties of the core in the displacement collaborative scanning experiment provided by an embodiment of the present application. In an exemplary embodiment, as Figure 9 shown, the device for obtaining the microscopic properties of the core in the displacement collaborative scanning experiment at least includes: an acquisition module 510, a reconstruction module 520, and a processing module 530.

[0138] The acquisition module 510 is configured to obtain a two-dimensional scanned image of the core in response to a microscopic property acquisition instruction during the displacement collaborative scanning experiment on the core.

[0139] A reconstruction module 520 for obtaining a three-dimensional core image by three-dimensionally reconstructing a two-dimensional scanned image, where the three-dimensional core image includes a three-dimensional structure of the porous medium of the core.

[0140] A processing module 530 for obtaining the oil-gas ratio of the core according to the temperature, pressure applied in the displacement co-scanning experiment and the two-phase phase diagram of the core, and identifying the oil-gas two-phase in the three-dimensional structure of the porous medium according to the oil-gas ratio of the core to obtain the three-dimensional spatial distribution of the oil and gas in the core, and the three-dimensional spatial distribution is used to guide oil and gas exploitation.

[0141] Based on any of the above-described embodiments, the processing module 530 is specifically configured to:

[0142] Locate the distribution of oil and gas in the three-dimensional core image according to the change in radiation attenuation indicated by the pixel points in the three-dimensional core image; identify the oil-gas two-phase in the three-dimensional structure of the porous medium according to the distribution of oil and gas in the three-dimensional core image and the oil-gas ratio of the core.

[0143] Based on any of the above-described embodiments, the processing module 530 is specifically configured to:

[0144] Obtain the attenuation coefficient of the pixel points corresponding to the oil and gas in the three-dimensional core image; locate the distribution of oil and gas in the three-dimensional core image according to the change in radiation attenuation indicated by the pixel points in the three-dimensional core image and the attenuation coefficient of the pixel points corresponding to the oil and gas.

[0145] Based on any of the above-described embodiments, the processing module 530 is further configured to:

[0146] Obtain quantitative description information on the occurrence state of oil and gas in the three-dimensional structure of the porous medium according to the three-dimensional spatial distribution of the oil and gas in the core; obtain the occurrence state of the oil and gas in the three-dimensional structure of the porous medium according to the quantitative description information on the occurrence state.

[0147] Based on any of the above-described embodiments, the quantitative description information on the occurrence state of the oil and gas includes a shape factor and / or a contact surface area ratio. The processing module 530 is specifically configured to:

[0148] Obtain the volume and surface area of the oil and gas according to the shape of the oil and gas in the three-dimensional structure of the porous medium in the core; obtain the shape factor of the oil and gas in the three-dimensional structure of the porous medium according to the volume and surface area of the oil and gas; and / or, obtain the contact area between the oil and gas and the pores according to the distribution of the oil and gas in the core and the oil-gas ratio; obtain the contact surface area ratio of the oil and gas in the three-dimensional structure of the porous medium according to the surface area of the oil and gas and the contact area between the oil and gas and the pores.

[0149] Based on any of the above-described embodiments, the quantitative description information on the occurrence state of the oil and gas includes the quantitative description information on the occurrence state of multiple oil and gas blocks. The processing module 530 is specifically configured to:

[0150] According to the quantitative description information of the occurrence state of each oil and gas block, determine the set judgment conditions satisfied by the quantitative description information of the occurrence state; according to the correlation relationship between the set judgment conditions and the oil and gas occurrence state, obtain the occurrence state of the oil and gas block.

[0151] The device of this embodiment can be used to execute the technical solutions of any of the above - shown method embodiments. The implementation principles and technical effects are similar and will not be elaborated here.

[0152] In an exemplary embodiment, an electronic device includes:

[0153] A processor; and a memory for storing executable instructions of the processor.

[0154] Wherein, the processor is configured to execute the method for obtaining the microscopic properties of the core in the displacement collaborative scanning experiment described in the above - mentioned embodiment by executing the executable instructions.

[0155] Figure 10 It is a schematic structural diagram of an electronic device provided in an embodiment of the present application. It should be noted that this electronic device is only an example adapted to the present invention and cannot be considered as providing any limitation to the scope of use of the present invention. This electronic device cannot be interpreted as requiring or necessarily having Figure 10 one or more components in the exemplary electronic device shown.

[0156] The hardware structure of this electronic device may vary greatly due to different configurations or performances. As Figure 10 shown, the electronic device 600 includes: a power supply 610, an interface 630, at least one memory 650, and at least one central processing unit (CPU) 670.

[0157] Wherein, the power supply 610 is used to provide working voltage for each hardware device on the electronic device 600.

[0158] The interface 630 includes at least one wired or wireless network interface 631, at least one serial - parallel conversion interface 633, at least one input - output interface 635, and at least one USB interface 637, etc., for communicating with external devices.

[0159] The memory 650 serves as a carrier for resource storage and can be a read-only memory, a random access memory, a magnetic disk, an optical disc, etc. The resources stored thereon include an operating system 651, application programs 653, or data 655, etc. The storage method can be transient storage or permanent storage. Among them, the operating system 651 is used to manage and control each hardware device and application program 653 on the electronic device 600 to enable the central processing unit 670 to perform calculations and processing on the massive data 655. It can be Windows ServerTM, Mac OS XTM, UnixTM, LinuxTM, FreeBSD TM, FreeRTOS, etc. The application program 653 is a computer program that completes at least one specific task based on the operating system 651. It can include at least one module ( Figure 10 not shown in the figure), and each module can separately contain a series of computer-readable instructions for the electronic device. The data 655 can be image data stored in a magnetic disk, etc.

[0160] The central processing unit 670 can include one or more processors and is set to communicate with the memory 650 through a bus for performing operations and processing the massive data 655 in the memory 650.

[0161] As described in detail above, the electronic device applicable to the present invention will complete the method for obtaining the microscopic properties of a core in a displacement collaborative scanning experiment in the form of a central processing unit 670 reading a series of computer-readable instructions stored in the memory.

[0162] In an exemplary embodiment, a computer-readable storage medium stores a computer program, and when the computer program is executed by a processor, it implements the method for obtaining the microscopic properties of a core in a displacement collaborative scanning experiment in each of the above embodiments.

[0163] The present application also provides a computer program product, including a computer program, and when the computer program is executed by a processor, it implements the solution of the method for obtaining the microscopic properties of a core in a displacement collaborative scanning experiment as described above.

[0164] Those of ordinary skill in the art can understand that all or part of the steps of implementing the above method embodiments can be completed by hardware related to program instructions. The foregoing program can be stored in a computer-readable storage medium. When the program is executed, it executes the steps including each of the above method embodiments; and the foregoing storage medium includes: various media such as ROM, RAM, magnetic disks, or optical discs that can store program codes.

[0165] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present application, rather than limiting them; although the present application has been described in detail with reference to the foregoing embodiments, those of ordinary skill in the art should understand that they can still modify the technical solutions described in the foregoing embodiments, or perform equivalent replacements on some or all of the technical features; and these modifications or replacements do not cause the essence of the corresponding technical solutions to deviate from the scope of the technical solutions of the embodiments of the present application.

Claims

1. A method for obtaining the microscopic properties of a core in a displacement collaborative scanning experiment, characterized in that, The method includes: During the process of performing a displacement collaborative scanning experiment on a core, in response to a core microscopic property acquisition instruction, obtaining a two-dimensional scanned image of the core; Obtaining a three-dimensional core image by performing three-dimensional reconstruction on the two-dimensional scanned image, where the three-dimensional core image includes a three-dimensional structure of the porous medium of the core; According to the temperature and pressure applied in the displacement collaborative scanning experiment and the two-phase phase diagram of the core, obtaining the oil-gas ratio of the core, and identifying the oil-gas two phases in the three-dimensional porous medium structure according to the oil-gas ratio of the core, to obtain the three-dimensional spatial distribution of the oil and gas in the core, where the three-dimensional spatial distribution is used to guide oil and gas exploitation; the two-phase phase diagram is a pressure-volume-temperature (PVT) relationship diagram corresponding to oil and gas, and the curve in the two-phase phase diagram represents the oil-gas volume under different oil-gas ratios.

2. The method according to claim 1, wherein The identifying the oil-gas two phases in the three-dimensional porous medium structure according to the oil-gas ratio of the core includes: Locating the distribution of the oil and gas in the three-dimensional core image according to the change in radiation attenuation indicated by the pixel points in the three-dimensional core image; Identifying the oil-gas two phases in the three-dimensional porous medium structure according to the distribution of the oil and gas in the three-dimensional core image and the oil-gas ratio of the core.

3. The method according to claim 2, wherein The locating the distribution of the oil and gas in the three-dimensional core image according to the change in radiation attenuation indicated by the pixel points in the three-dimensional core image includes: Obtaining the attenuation coefficient of the pixel points corresponding to the oil and gas in the three-dimensional core image; Locating the distribution of the oil and gas in the three-dimensional core image according to the change in radiation attenuation indicated by the pixel points in the three-dimensional core image and the attenuation coefficient of the pixel points corresponding to the oil and gas.

4. The method according to any one of claims 1 to 3, characterized in that The method further includes: Obtaining quantitative description information on the occurrence state of the oil and gas in the three-dimensional porous medium structure according to the three-dimensional spatial distribution of the oil and gas in the core; Obtaining the occurrence state of the oil and gas in the three-dimensional porous medium structure according to the quantitative description information on the occurrence state.

5. The method according to claim 4, wherein The quantitative description information on the occurrence state includes a shape factor and / or a contact surface area ratio. The obtaining the quantitative description information on the occurrence state of the oil and gas in the three-dimensional porous medium structure according to the three-dimensional spatial distribution of the oil and gas in the core includes: Obtaining the volume and surface area of the oil and gas according to the shape of the oil and gas in the three-dimensional porous medium structure in the core; obtaining the shape factor of the oil and gas in the three-dimensional porous medium structure according to the volume and surface area of the oil and gas; and / or, Obtaining the contact area between the oil and gas and the pores according to the distribution of the oil and gas in the core and the oil-gas ratio; obtaining the contact surface area ratio of the oil and gas in the three-dimensional porous medium structure according to the surface area of the oil and gas and the contact area between the oil and gas and the pores.

6. The method according to claim 4, wherein The quantitative description information on the occurrence state of the oil and gas includes the quantitative description information on the occurrence state of multiple oil and gas blocks. The obtaining the occurrence state of the oil and gas in the three-dimensional porous medium structure according to the quantitative description information on the occurrence state includes: Determining the set judgment conditions satisfied by the quantitative description information on the occurrence state according to the quantitative description information on the occurrence state of each oil and gas block; Based on the correlation between the set judgment conditions and the occurrence state of oil and gas, the occurrence state of the oil and gas block is obtained.

7. An apparatus for obtaining the microscopic properties of a core in a displacement synergy scanning experiment, characterized in that, The device includes: An acquisition module, configured to acquire a two-dimensional scanned image of the core in response to a core microscopic property acquisition instruction during the process of performing a displacement collaborative scanning experiment on the core; A reconstruction module, configured to obtain a three-dimensional core image by performing three-dimensional reconstruction on the two-dimensional scanned image, where the three-dimensional core image includes a three-dimensional structure of the porous medium of the core; A processing module, configured to obtain the oil and gas proportion of the core according to the temperature and pressure applied in the displacement collaborative scanning experiment and the two-phase phase diagram of the core, and identify the oil and gas two-phase in the three-dimensional structure of the porous medium according to the oil and gas proportion of the core, so as to obtain the three-dimensional spatial distribution of the oil and gas in the core, and the three-dimensional spatial distribution is used to guide oil and gas exploitation; the two-phase phase diagram is a pressure-volume-temperature (PVT) relationship diagram corresponding to oil and gas, and the curve in the two-phase phase diagram represents the oil and gas volume under different oil and gas proportions.

8. An electronic device, characterized in that, It includes: A processor; And A memory, configured to store executable instructions of the processor; Wherein, the processor is configured to execute the method for acquiring the microscopic properties of the core in the displacement collaborative scanning experiment according to any one of claims 1 to 6 by executing the executable instructions.

9. A computer-readable storage medium having a computer program stored thereon, characterized in that, When the computer program is executed by the processor, it implements the method for acquiring the microscopic properties of the core in the displacement collaborative scanning experiment according to any one of claims 1 to 6.

10. A computer program product, comprising a computer program, characterized in that, When the computer program is executed by the processor, it implements the method for acquiring the microscopic properties of the core in the displacement collaborative scanning experiment according to any one of claims 1 - 6.

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