Shale oil evaluation method and device, electronic equipment and storage medium
Through X-ray diffraction mineral analysis and high-frequency two-dimensional nuclear magnetic T1-T2 detection technology, the problem of inaccurate shale oil evaluation in the existing technology is solved, and accurate quantitative characterization of shale oil under the original pore structure is realized, supporting the selection and development of favorable areas.
Patent Information
- Application Number
- CN202410069661.3
- Authority / Receiving Office
- CN · China
- Patent Type
- Applications(China)
- Current Assignee / Owner
- Filing Date
- 2024-01-17
- Publication Date
- 2025-07-18
AI Technical Summary
The prior art cannot accurately evaluate the free oil amount and adsorbed oil amount of shale oil while maintaining the pore structure of shale. The pyrolysis experiment results in damage to the pore structure and the test results are inaccurate.
The shale stalk phase was determined by X-ray diffraction mineral analysis and TOC test. Combined with high-pressure mercury inverted and nitrogen adsorption experiments and high-frequency two-dimensional nuclear magnetic T1-T2 detection technology, the free oil pore size distribution and adsorbed oil pore size distribution of different shale stalk phases were obtained, and the free oil amount and adsorbed oil amount were measured under the original pore structure.
Accurately characterizing the free oil quantity and adsorbed oil quantity of shale oil under the condition of maintaining the original pore structure is achieved, helping to select and develop favorable areas, and eliminating the impact of pore structure failure.
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Figure CN120334265A_ABST
Abstract
Description
Technical Field
[0001] The present application relates to the technical field of geological exploration, and particularly to a method, device, electronic device and storage medium for evaluating shale oil. Background Art
[0002] Shale oil mainly exists in free and adsorbed states in the original formation. Adsorbed shale oil is mainly adsorbed on the surfaces of organic matter and inorganic mineral particles and is difficult to be produced; while free shale oil mainly exists in inorganic pores and fractures and is easy to develop. The free oil content of shale oil is an important evaluation parameter in the development process of shale oil. At present, the research on the free oil content of shale oil in different shale lithofacies is still in its infancy. The shale lithofacies types are mainly determined by TOC testing and whole-rock X-ray diffraction analysis, and then the free oil volume and adsorbed oil volume of shale oil in different shale lithofacies are obtained through stepwise pyrolysis experiments.
[0003] However, in the preparation stage before the pyrolysis experiment, the shale samples need to be crushed, which inevitably damages the pore structure of the shale and makes it difficult to characterize the original occurrence characteristics of shale oil in the formation. At the same time, the loss of light hydrocarbons during the storage of the samples also makes the test results inaccurate. Using molecular dynamics simulation to characterize the microscopic occurrence characteristics of shale oil is a new method that has emerged in recent years. However, due to the complexity of petroleum components and mineral models, it is difficult for molecular dynamics simulation to accurately characterize the free oil content of shale oil at the core scale.
[0004] It should be noted that the information disclosed in the background art part of the present application is only intended to deepen the understanding of the general background art of the present application, and should not be regarded as an admission or any form of implication that this information constitutes the prior art known to those skilled in the art. Summary of the Invention
[0005] In view of this, the present application provides a method, device, electronic device and storage medium for evaluating shale oil, which is conducive to solving the problem that the free oil volume and adsorbed oil volume in shale oil cannot be accurately evaluated in the prior art.
[0006] In a first aspect, an embodiment of the present application provides a method for evaluating shale oil in different shale lithofacies, including:
[0007] Determine one or more shale lithofacies in the target area;
[0008] Obtain the free oil pore size distribution characteristics and adsorbed oil pore size distribution characteristics in each of the shale lithofacies;
[0009] Obtain the free oil volume and adsorbed oil volume in each of the shale lithofacies under the condition of the original pore structure.
[0010] In a possible implementation, determining one or more shale lithofacies of the target area includes:
[0011] Performing X-ray diffraction mineral analysis on the shale samples in the target area to obtain mineral components and contents;
[0012] Performing a TOC test on the shale samples in the target area to obtain the TOC content;
[0013] Determining one or more shale lithofacies of the target area based on the mineral components and contents and the TOC content.
[0014] In a possible implementation, obtaining the free oil pore size distribution characteristics and adsorbed oil pore size distribution characteristics in each of the shale lithofacies includes:
[0015] Respectively obtaining the first shale pore size distribution characteristic, the second shale pore size distribution characteristic, and the third shale pore size distribution characteristic of each of the shale lithofacies;
[0016] Comparing the first shale pore size distribution characteristic and the second shale pore size distribution characteristic of each of the shale lithofacies to obtain the free oil pore size distribution characteristic of each of the shale lithofacies;
[0017] Comparing the second shale pore size distribution characteristic and the third shale pore size distribution characteristic of each of the shale lithofacies to obtain the adsorbed oil pore size distribution characteristic of each of the shale lithofacies;
[0018] Wherein, the first shale pore size distribution characteristic is the shale pore size distribution characteristic under the original pore structure condition, the second shale pore size distribution characteristic is the shale pore size distribution characteristic after free oil extraction, and the third shale pore size distribution characteristic is the shale pore size distribution characteristic after sequential free oil extraction and adsorbed oil extraction.
[0019] In a possible implementation, obtaining the first shale pore size distribution characteristic of each of the shale lithofacies includes:
[0020] Performing high-pressure mercury injection and nitrogen adsorption experiments on the samples of each of the shale lithofacies respectively to obtain the first shale pore size distribution characteristic of each of the shale lithofacies.
[0021] In a possible implementation, obtaining the second shale pore size distribution characteristic of each of the shale lithofacies includes:
[0022] Using dichloromethane to extract free oil from the samples of each of the shale lithofacies;
[0023] Performing high-pressure mercury injection and nitrogen adsorption experiments on the samples from which free oil has been extracted respectively to obtain the second shale pore size distribution characteristic of each of the shale lithofacies.
[0024] In a possible implementation, obtaining the third shale pore size distribution characteristics of each of the shale lithofacies includes:
[0025] Successively using dichloromethane and trichloromethane to extract free oil and adsorbed oil from the samples of each of the shale lithofacies;
[0026] Performing high-pressure mercury intrusion and nitrogen adsorption experiments on the samples from which the free oil and adsorbed oil have been extracted respectively to obtain the third shale pore size distribution characteristics of each of the shale lithofacies.
[0027] In a possible implementation, obtaining the amount of free oil and adsorbed oil of each of the shale lithofacies under the original pore structure conditions includes:
[0028] Using high-frequency two-dimensional nuclear magnetic T1-T2 detection technology to test the core samples of each of the shale lithofacies to obtain the amount of free oil and adsorbed oil of each of the shale lithofacies under the original pore structure conditions.
[0029] In a possible implementation, before using the high-frequency two-dimensional nuclear magnetic T1-T2 detection technology to test the core samples of each of the shale lithofacies, the method further includes:
[0030] Using cryogenic nitrogen technology to preserve the core samples of each of the shale lithofacies.
[0031] In a second aspect, an embodiment of the present application provides an evaluation device for shale oil in different shale lithofacies, including:
[0032] A shale lithofacies determination module for determining one or more shale lithofacies of a target area;
[0033] A pore size distribution characteristic acquisition module for acquiring the free oil pore size distribution characteristic and the adsorbed oil pore size distribution characteristic in each of the shale lithofacies;
[0034] An oil amount acquisition module for acquiring the amount of free oil and adsorbed oil of each of the shale lithofacies under the original pore structure conditions.
[0035] In a third aspect, an embodiment of the present application provides an electronic device, including:
[0036] A processor;
[0037] A memory;
[0038] And a computer program, where the computer program is stored in the memory, and the computer program includes instructions that, when executed by the processor, cause the electronic device to execute the method according to any one of the first aspect.
[0039] Fourthly, embodiments of the present application provide a computer-readable storage medium. The computer-readable storage medium includes a stored program. When the program runs, it controls the device where the computer-readable storage medium is located to execute the method according to any one of the first aspect.
[0040] In the embodiments of the present application, under the condition of maintaining the original pore structure, the free oil content and adsorbed oil content in different shale lithofacies can be quantitatively characterized, which is of great significance for the selection and development of favorable areas for shale oil. In addition, the influence of pore size distribution characteristics on the free oil content and adsorbed oil content can also be studied. BRIEF DESCRIPTION OF THE DRAWINGS
[0041] In order to more clearly illustrate the technical solutions of the embodiments of the present application, the following will briefly introduce the drawings required in the embodiments. Obviously, the drawings in the following description are only 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.
[0042] Figure 1 Schematic flow chart of a method for evaluating shale oil in different shale lithofacies provided by an embodiment of the present application;
[0043] Figure 2 Schematic diagram of a ternary diagram of silicate minerals, carbonate minerals and clay minerals provided by an embodiment of the present application;
[0044] Figure 3 Schematic diagram of the distribution ranges of free oil and adsorbed oil in a high-frequency two-dimensional nuclear magnetic resonance T1-T2 spectrum provided by an embodiment of the present application;
[0045] Figure 4 Schematic diagram of shale lithofacies division provided by an embodiment of the present application;
[0046] Figure 5A Schematic diagram of the pore size distribution characteristics of organic matter-bearing clay shale provided by an embodiment of the present application;
[0047] Figure 5B Schematic diagram of the pore size distribution characteristics of organic matter-bearing calcareous shale provided by an embodiment of the present application;
[0048] Figure 6A Schematic diagram of the high-frequency two-dimensional nuclear magnetic resonance T1-T2 test results of organic matter-bearing clay shale provided by an embodiment of the present application;
[0049] Figure 6B Schematic diagram of the high-frequency two-dimensional nuclear magnetic resonance T1-T2 test results of organic matter-bearing calcareous shale provided by an embodiment of the present application;
[0050] Figure 7A structural block diagram of an evaluation device for shale oil in different shale lithofacies provided by an embodiment of the present application;
[0051] Figure 8 A schematic structural diagram of an electronic device provided by an embodiment of the present application. Detailed implementation manners
[0052] For a better understanding of the technical solutions of the present application, the embodiments of the present application will be described in detail below with reference to the accompanying drawings.
[0053] It should be clear that the described embodiments are only a part of the embodiments of the present application, rather than all the embodiments. All other embodiments obtained by those of ordinary skill in the art based on the embodiments in the present application without creative efforts shall fall within the protection scope of the present application.
[0054] The terms used in the embodiments of the present application are only for the purpose of describing specific embodiments, and are not intended to limit the present application. The singular forms of "a", "the" and "said" used in the embodiments of the present application and the appended claims are also intended to include the plural forms unless the context clearly indicates otherwise.
[0055] It should be understood that the term " / and" used herein is only a description of the association relationship of associated objects, indicating that three relationships may exist. For example, A and / or B may represent: A exists alone, A and B exist simultaneously, and B exists alone. In addition, the character " / " herein generally represents an "or" relationship between the associated objects before and after.
[0056] In view of the above problems, the embodiments of the present application provide an evaluation method for shale oil in different shale lithofacies, which can quantitatively characterize the free oil content and adsorbed oil content in different shale lithofacies under the condition of maintaining the original pore structure, and is of great significance for the selection and development of favorable areas of shale oil. In addition, the influence of pore size distribution characteristics on the free oil content and adsorbed oil content can also be studied. Details will be described below in combination with specific implementation manners.
[0057] See Figure 1 , a schematic flow chart of an evaluation method for shale oil in different shale lithofacies provided by an embodiment of the present application. As Figure 1 shown, it mainly includes the following steps.
[0058] Step S101: Determine one or more shale lithofacies in the target area.
[0059] Specifically, the shale samples in the target area are crushed and then subjected to X-ray diffraction mineral analysis to obtain the mineral components and contents. Then, the crushed shale samples in the target area are subjected to TOC testing to obtain the TOC content. Based on the mineral components and contents and the TOC content, one or more shale lithofacies in the target area are determined.
[0060] Exemplarily, the shale samples are dried and crushed to 200 mesh; the dried and crushed shale samples are subjected to X-ray diffraction mineral analysis to obtain the mineral components and contents; the dried and crushed shale samples are subjected to TOC testing to obtain the TOC content; the shale lithofacies are determined based on the ternary diagram of silicate minerals (quartz + feldspar), carbonate minerals, and clay minerals (as Figure 2 shown) and the TOC content.
[0061] Specifically, they are classified into clay shale lithofacies (clay mineral content greater than 50%), calcareous shale lithofacies (carbonate mineral content greater than 50%), siliceous shale lithofacies (siliceous mineral greater than 50%), and mixed shale lithofacies (the three types of minerals are between 25% and 50%) according to the mineral components and contents, and are classified into lean organic matter shale (TOC < 1%), organic matter-containing shale (1% < TOC < 2%), and rich organic matter shale (TOC > 2%) according to the TOC content. It can be understood that by combining the mineral components and contents with the TOC content, the shale lithofacies can be classified into: lean organic matter clay shale, organic matter-containing clay shale, rich organic matter clay shale; lean organic matter calcareous shale, organic matter-containing calcareous shale, rich organic matter calcareous shale; lean organic matter siliceous shale, organic matter-containing siliceous shale, rich organic matter siliceous shale; lean organic matter mixed shale, organic matter-containing mixed shale, rich organic matter mixed shale.
[0062] Step S102: Obtain the free oil pore size distribution characteristics and adsorbed oil pore size distribution characteristics in each of the shale lithofacies.
[0063] Specifically, the first shale pore size distribution characteristics, the second shale pore size distribution characteristics, and the third shale pore size distribution characteristics of each of the shale lithofacies are obtained respectively; the first shale pore size distribution characteristics and the second shale pore size distribution characteristics of each of the shale lithofacies are compared to obtain the free oil pore size distribution characteristics of each of the shale lithofacies; the second shale pore size distribution characteristics and the third shale pore size distribution characteristics of each of the shale lithofacies are compared to obtain the adsorbed oil pore size distribution characteristics of each of the shale lithofacies; wherein, the first shale pore size distribution characteristics are the shale pore size distribution characteristics under the original pore structure conditions, the second shale pore size distribution characteristics are the shale pore size distribution characteristics after free oil extraction, and the third shale pore size distribution characteristics are the shale pore size distribution characteristics after sequential extraction of free oil and adsorbed oil.
[0064] In one possible implementation, obtaining the first shale pore size distribution characteristics of each of the shale lithofacies includes: separately performing high-pressure mercury intrusion and nitrogen adsorption experiments on samples of each of the shale lithofacies to obtain the first shale pore size distribution characteristics of each of the shale lithofacies.
[0065] In one possible implementation, obtaining the second shale pore size distribution characteristics of each of the shale lithofacies includes: extracting free oil from samples of each of the shale lithofacies using dichloromethane; separately performing high-pressure mercury intrusion and nitrogen adsorption experiments on the samples from which the free oil has been extracted to obtain the second shale pore size distribution characteristics of each of the shale lithofacies.
[0066] In one possible implementation, obtaining the third shale pore size distribution characteristics of each of the shale lithofacies includes: sequentially extracting free oil and adsorbed oil from samples of each of the shale lithofacies using dichloromethane and trichloromethane; separately performing high-pressure mercury intrusion and nitrogen adsorption experiments on the samples from which the free oil and adsorbed oil have been extracted to obtain the third shale pore size distribution characteristics of each of the shale lithofacies.
[0067] In a specific implementation, shale samples at the same sampling point can be divided into three parallel samples, namely group A, group B, and group C. The samples in group A are not processed and directly undergo high-pressure mercury intrusion and nitrogen adsorption experiments to obtain the first shale pore size distribution characteristics of the samples in group A. The samples in group B are extracted with dichloromethane (to extract free oil) and then separately undergo high-pressure mercury intrusion and nitrogen adsorption experiments to obtain the second shale pore size distribution characteristics of the samples in group B. The samples in group C are first extracted with dichloromethane (to extract free oil) and then extracted with trichloromethane (to extract adsorbed oil), and then separately undergo high-pressure mercury intrusion and nitrogen adsorption experiments to obtain the third shale pore size distribution characteristics of the samples in group C.
[0068] Step S103: Obtain the free oil content and adsorbed oil content of each of the shale lithofacies under the original pore structure conditions.
[0069] Specifically, core samples are taken from a shale oil well, and the core samples of the shale lithofacies are preserved using cryogenic nitrogen technology to preserve the original hydrocarbon components and avoid the loss of light hydrocarbons. Then, a high-frequency two-dimensional nuclear magnetic resonance T1-T2 detection technology is used to test the core samples of each of the shale lithofacies to obtain the free oil content and adsorbed oil content of each of the shale lithofacies under the original pore structure conditions. The distribution ranges of free oil and adsorbed oil in the high-frequency two-dimensional nuclear magnetic resonance T1-T2 spectrum are as Figure 3 shown.
[0070] The embodiments of the present application have established a set of evaluation methods for the free oil content and adsorbed oil content of shale oil in different shale lithofacies under the original pore structure conditions, excluded the influence of pore structure damage on the occurrence characteristics of shale oil, and are of great significance for the selection and development of favorable areas for shale oil.
[0071] For ease of understanding, the following describes in detail the technical solution provided by the embodiments of the present application in combination with a specific application scenario.
[0072] Step 1: Taking the Daanzhai section of the Ziliujing Formation in the Jurassic of the Sichuan Basin as an example, X-ray diffraction mineral analysis and TOC tests are carried out to obtain the mineral components and contents as well as the TOC content, as shown in Table 1.
[0073] Table 1:
[0074]
[0075] Based on the ternary diagram of silicate minerals, carbonate minerals and clay minerals and the TOC content, the Daanzhai shale lithofacies are divided into 6 shale lithofacies: organic-rich clay shale, organic-bearing clay shale, organic-poor clay shale, organic-bearing mixed shale, organic-poor mixed shale and organic-poor calcareous shale, as Figure 4 shown.
[0076] Step 2: Select samples of different shale lithofacies. Each sample is divided into four parallel samples A, B, C, and D. The samples in group A are not treated. The samples in group B are extracted with dichloromethane for 1 hour to extract free oil. After the samples in group C are extracted with dichloromethane for 1 hour, they are then extracted with chloroform for 1 hour to extract adsorbed oil. The samples in group D are prepared into standard cores with a length of 5 cm and a diameter of 2 cm for step 3. The samples in group A are divided into A1 and A2 to conduct high-pressure mercury intrusion and nitrogen adsorption experiments respectively to obtain the pore size distribution characteristics of the shale. The samples in group B are divided into B1 and B2 to conduct high-pressure mercury intrusion and nitrogen adsorption experiments respectively, and compared with the samples in group A to determine the pore size distribution characteristics of free oil in different shale lithofacies. The samples in group C are divided into C1 and C2 to conduct high-pressure mercury intrusion and nitrogen adsorption experiments respectively, and compared with the samples in group A and group B to determine the pore size distribution characteristics of adsorbed oil in different shale lithofacies. In the nitrogen adsorption experiment, the shale core is crushed into 50-80 mesh and placed in an oven at 60 °C for drying for 24 h to remove moisture and impurity gases in the pores, and then it is degassed in a vacuum environment at 60 °C for 12 hours to complete the pretreatment. At a temperature of -196 °C (77K), nitrogen is used as the adsorption medium to measure the gas adsorption amount at different relative pressures. The shale sample used in the high-pressure mercury intrusion experiment is a plunger sample with a diameter of 2 cm and a length of 2.5 cm. It is dried to a constant weight at 105 °C before the test, and the highest experimental pressure is 200 MPa. According to the experimental results, the adsorbed shale oil in the organic-bearing clay shale is distributed in the pore size of 1.7-8.6 nm, and the free shale oil is distributed in the pore size of 16.3-95 nm ( Figure 5A ); the adsorbed shale oil in the organic-bearing calcareous shale is distributed in the pore size of 1.5-8.1 nm, and the free shale oil is distributed in the pore size of 15-102 nm ( Figure 5B ).
[0077] Step 3: Test the sample D in Step 2 using the high-frequency two-dimensional nuclear magnetic T1-T2 detection technology to obtain the characteristics of the free oil and adsorbed oil contents of shale oil in different shale lithofacies, such as Figure 6A and Figure 6B shown. The positions in the T1-T2 diagram that can distinguish shale oil with different free oil contents are used to determine the distribution ranges of adsorbed and free shale oil using the high-frequency two-dimensional nuclear magnetic T1-T2 spectrum, calculate the adsorbed oil amount and free oil amount in the shale lithofacies, and combine the pore size distributions of adsorbed oil and free oil in Step 2 to finally obtain the distribution pore sizes and contents of adsorbed oil and free oil in different shale lithofacies.
[0078] The results show that for the organic matter-containing clay shale, due to the strong adsorption ability of organic matter and clay minerals, the shale oil mainly appears in the adsorbed state. The adsorbed oil signal in the T1-T2 spectrum is 9.96 μl / g, accounting for 81.0% of the total shale oil amount, distributed in the pore size range of 1.7 - 8.6 nm, and the free oil is 2.33 μl / g, accounting for 19.0% of the total shale oil amount, distributed in the pore size range of 16.3 - 95 nm ( Figure 5A and Figure 6A ). For the organic matter-containing calcareous shale, the calcite has a weak adsorption ability. The shale oil appears in the adsorbed state in the organic matter, and there is also a part in the free state in the pore spaces with calcite as the matrix. The adsorbed state signal in the T1-T2 spectrum is 1.64 μl / g, accounting for 26.4% of the total shale oil amount, distributed in the pore size range of 1.5 - 8.1 nm, and the free state signal is 4.56 μl / g, accounting for 73.6% of the total signal, distributed in the pore size range of 15 - 102 nm ( Figure 5B and Figure 6B ).
[0079] Corresponding to the above embodiments, the present application also provides an evaluation device for shale oil in different shale lithofacies.
[0080] See Figure 7 , which is a structural block diagram of an evaluation device for shale oil in different shale lithofacies provided by an embodiment of the present application. As Figure 7 shown, it mainly includes the following modules.
[0081] The shale lithofacies determination module 701 is used to determine one or more shale lithofacies in the target area;
[0082] The pore size distribution characteristic acquisition module 702 is used to acquire the free oil pore size distribution characteristics and adsorbed oil pore size distribution characteristics in each of the shale lithofacies;
[0083] The oil amount acquisition module 703 is used to acquire the free oil amount and adsorbed oil amount in each of the shale lithofacies under the original pore structure conditions.
[0084] It should be noted that for the specific content involved in the embodiments of the present application, reference may be made to the description of the above method embodiments. For the sake of brevity, it will not be repeated here.
[0085] Corresponding to the above embodiments, the embodiments of the present application further provide an electronic device.
[0086] See Figure 8 , which is a schematic structural diagram of an electronic device provided by an embodiment of the present application. As Figure 8 shown, the electronic device 800 may include: a processor 801, a memory 802, and a communication unit 803. These components communicate through one or more buses. Those skilled in the art can understand that the structure of the electronic device shown in the figure does not constitute a limitation on the embodiments of the present application. It can be a bus structure, a star structure, and may also include more or fewer components than shown in the figure, or combine certain components, or have different component arrangements.
[0087] Among them, the communication unit 803 is used to establish a communication channel so that the electronic device can communicate with other devices.
[0088] The processor 801 is the control center of the electronic device, connecting various parts of the entire electronic device through various interfaces and lines. By running or executing software programs and / or modules stored in the memory 802, and calling data stored in the memory, it executes various functions of the electronic device and / or processes data. The processor may be composed of an integrated circuit (IC). For example, it may be composed of a single packaged IC, or may be composed of multiple packaged ICs with the same or different functions connected together. For example, the processor 801 may only include a central processing unit (CPU). In the embodiment of the present application, the CPU may be a single operation core or may include multiple operation cores.
[0089] The memory 802 is used to store the execution instructions of the processor 801. The memory 802 can be implemented by any type of volatile or non-volatile storage device or a combination thereof, such as static random access memory (SRAM), electrically erasable programmable read-only memory (EEPROM), erasable programmable read-only memory (EPROM), programmable read-only memory (PROM), read-only memory (ROM), magnetic memory, flash memory, a magnetic disk, or an optical disc.
[0090] When the execution instructions in the memory 802 are executed by the processor 801, the electronic device 800 can execute some or all of the steps in the above method embodiments.
[0091] Corresponding to the above embodiments, an embodiment of the present application also provides a computer-readable storage medium. The computer-readable storage medium can store a program. When the program runs, it can control the device where the computer-readable storage medium is located to execute some or all of the steps in the above method embodiments. In a specific implementation, the computer-readable storage medium can be a magnetic disk, an optical disk, a read-only memory (ROM for short), a random access memory (RAM for short), or the like.
[0092] Corresponding to the above embodiments, an embodiment of the present application also provides a computer program product. The computer program product includes executable instructions. When the executable instructions are executed on a computer, the computer is enabled to execute some or all of the steps in the above method embodiments.
[0093] In the embodiments of the present application, "at least one" means one or more, and "a plurality" means two or more. "And / or" describes the association relationship of associated objects and indicates that three relationships can exist. For example, A and / or B can represent the cases of A existing alone, A and B existing simultaneously, and B existing alone. Where A and B can be singular or plural. The character " / " generally indicates that the associated objects before and after are in an "or" relationship. "At least one of the following" and its similar expressions refer to any combination of these items, including any combination of single items or plural items. For example, at least one of a, b, and c can represent: a, b, c, a - b, a - c, b - c, or a - b - c, where a, b, and c can be single or multiple.
[0094] Those of ordinary skill in the art can realize that the units and algorithm steps described in the embodiments disclosed herein can be implemented by a combination of electronic hardware, computer software, and electronic hardware. Whether these functions are executed in a hardware or software manner depends on the specific application and design constraints of the technical solution. Professional technicians can use different methods to implement the described functions for each specific application, but such implementation should not be considered to exceed the scope of the present application.
[0095] Those skilled in the art can clearly understand that for the convenience and conciseness of description, the specific working processes of the systems, devices, and units described above can refer to the corresponding processes in the foregoing method embodiments and will not be elaborated herein.
[0096] In several embodiments provided by the present application, if any function is implemented in the form of a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of the present application, in essence, or the part that contributes to the prior art, or a part of this technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions for causing a computer device (which may be a personal computer, a server, or a network device, etc.) to execute all or part of the steps of the methods described in various embodiments of the present application. The foregoing storage medium includes: various media that can store program codes, such as USB flash drives, mobile hard disks, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical discs.
[0097] The above is only the specific implementation manner of the present application. Any person skilled in the art within the technical scope disclosed by the present application can easily think of changes or substitutions, which should all be covered by the protection scope of the present application. The protection scope of the present application shall be subject to the protection scope of the claims.
Claims
1. A method for evaluating shale oil in different shale lithofacies, characterized in that, Comprising: Determining one or more shale lithofacies in a target area; Obtaining the free oil pore size distribution characteristics and adsorbed oil pore size distribution characteristics in each of the shale lithofacies; Obtaining the free oil quantity and adsorbed oil quantity in each of the shale lithofacies under the condition of the original pore structure.
2. The method according to claim 1, wherein The determining of one or more shale lithofacies in the target area includes: Performing X-ray diffraction mineral analysis on shale samples in the target area to obtain mineral components and contents; Performing TOC testing on the shale samples in the target area to obtain the TOC content; Determining one or more shale lithofacies in the target area according to the mineral components and contents and the TOC content.
3. The method according to claim 1, wherein The obtaining of the free oil pore size distribution characteristics and adsorbed oil pore size distribution characteristics in each of the shale lithofacies includes: Respectively obtaining the first shale pore size distribution characteristic, the second shale pore size distribution characteristic and the third shale pore size distribution characteristic of each of the shale lithofacies; Comparing the first shale pore size distribution characteristic and the second shale pore size distribution characteristic of each of the shale lithofacies to obtain the free oil pore size distribution characteristic of each of the shale lithofacies; Comparing the second shale pore size distribution characteristic and the third shale pore size distribution characteristic of each of the shale lithofacies to obtain the adsorbed oil pore size distribution characteristic of each of the shale lithofacies; Wherein, the first shale pore size distribution characteristic is the shale pore size distribution characteristic under the condition of the original pore structure, the second shale pore size distribution characteristic is the shale pore size distribution characteristic after free oil extraction, and the third shale pore size distribution characteristic is the shale pore size distribution characteristic after free oil and adsorbed oil extraction.
4. The method according to claim 3, wherein Obtaining the first shale pore size distribution characteristic of each of the shale lithofacies includes: Respectively performing high-pressure mercury injection and nitrogen adsorption experiments on samples of each of the shale lithofacies to obtain the first shale pore size distribution characteristic of each of the shale lithofacies.
5. The method according to claim 3, characterized in that Obtaining the second shale pore size distribution characteristic of each of the shale lithofacies includes: Using dichloromethane to extract free oil in samples of each of the shale lithofacies; Respectively performing high-pressure mercury injection and nitrogen adsorption experiments on the samples from which free oil has been extracted to obtain the second shale pore size distribution characteristic of each of the shale lithofacies.
6. The method according to claim 3, characterized in that, Obtaining the third shale pore size distribution characteristic of each of the shale lithofacies includes: Successively using dichloromethane and chloroform to extract free oil and adsorbed oil in samples of each of the shale lithofacies; Respectively performing high-pressure mercury injection and nitrogen adsorption experiments on the samples from which free oil and adsorbed oil have been extracted to obtain the third shale pore size distribution characteristic of each of the shale lithofacies.
7. The method according to claim 1, characterized in that, The obtaining of the free oil quantity and adsorbed oil quantity in each of the shale lithofacies under the condition of the original pore structure includes: Testing core samples of each of the shale lithofacies by using high-frequency two-dimensional nuclear magnetic T1-T2 detection technology to obtain the free oil quantity and adsorbed oil quantity in each of the shale lithofacies under the condition of the original pore structure.
8. The method according to claim 7, characterized in that, Before the testing of core samples of each of the shale lithofacies by using high-frequency two-dimensional nuclear magnetic T1-T2 detection technology, the method further includes: Preserving core samples of each of the shale lithofacies by using cryogenic nitrogen technology.
9. An evaluation device for shale oil in different shale lithofacies, characterized in that, Comprising: A shale lithofacies determination module, configured to determine one or more shale lithofacies of a target area; An aperture distribution characteristic acquisition module, configured to acquire the free oil aperture distribution characteristic and the adsorbed oil aperture distribution characteristic in each of the shale lithofacies; An oil quantity acquisition module, configured to acquire the free oil quantity and the adsorbed oil quantity in each of the shale lithofacies under the original pore structure condition.
10. An electronic device, characterized in that, Comprising: A processor; A memory; And a computer program, wherein the computer program is stored in the memory, and the computer program includes instructions, when the instructions are executed by the processor, enabling the electronic device to execute the method according to any one of claims 1 to 8.
11. A computer-readable storage medium, characterized in that, The computer-readable storage medium includes a stored program, wherein, when the program runs, it controls the device where the computer-readable storage medium is located to execute the method according to any one of claims 1 to 8.