Shale hydrocarbon expulsion efficiency evaluation method, device, equipment and medium

Abstract

The invention discloses a shale hydrocarbon expulsion efficiency evaluation method, device, equipment and medium, and relates to the technical field of shale gas exploration and developing.The shale hydrocarbon expulsion efficiency evaluation method includes the steps that hydrocarbon generation quantity charts of shale under different total organic carbon TOC grades are constructed; testing the water saturation of the core sample of the shale to obtain the water saturation rate of the core sample; carrying out oil washing treatment on the rock core sample, and carrying out porosity test to obtain rock porosity and rock apparent density; obtaining a crude oil sample of a production layer where the core sample is located, and performing a crude oil physical property experiment to obtain crude oil density; when key parameters such as water saturation rate, rock porosity, rock apparent density, crude oil density and shale hydrocarbon generation quantity charts under different total organic carbon TOC grades of a core sample and key parameters of hydrocarbon release and migration in a hydrocarbon expulsion process are measured, a dynamic measurement process is adopted, and the dynamic measurement process can realize dynamic simulation of a hydrocarbon migration path; and finally, accurate evaluation of the shale hydrocarbon expulsion efficiency is realized.

Description

Technical Field

[0001] The present invention relates to the technical field of shale gas exploration and development, and particularly relates to a method, device, equipment and medium for evaluating shale hydrocarbon expulsion efficiency. Background Art

[0002] As an important part of unconventional oil and gas resources, the hydrocarbon expulsion efficiency of shale oil is a key indicator for measuring the recoverability of shale oil resources and the degree of hydrocarbon enrichment, and is of great significance for the resource potential evaluation and economic feasibility analysis of the target reservoir. Therefore, accurately calculating the hydrocarbon expulsion efficiency of shale is an important technical link in shale oil and gas exploration and development.

[0003] At present, the evaluation of shale oil hydrocarbon expulsion efficiency mainly relies on the hydrocarbon generation potential method and the material balance method; the material balance method focuses on the evaluation of theoretical hydrocarbon generation amount and does not effectively combine the characteristics of hydrocarbon release and migration during the hydrocarbon expulsion process. The hydrocarbon generation potential method usually uses the hydrocarbon generation amount chart or empirical formula of shale to predict the hydrocarbon generation amount, without considering the hydrocarbon release, migration and residue during the hydrocarbon expulsion process. Therefore, the traditional hydrocarbon generation potential method and material balance method focus on static calculation modes such as theory or empirical formulas, and do not take into account the hydrocarbon release and migration during the hydrocarbon expulsion process, as well as the residue of hydrocarbons, resulting in a low accuracy of the evaluated shale hydrocarbon expulsion efficiency. Summary of the Invention

[0004] Embodiments of the present invention provide a method, device, equipment and medium for evaluating shale hydrocarbon expulsion efficiency, which can solve the problem in the prior art that the traditional hydrocarbon generation potential method and material balance method focus on static calculation modes such as theory or empirical formulas, and do not take into account the hydrocarbon release and migration during the hydrocarbon expulsion process, as well as the residue of hydrocarbons, resulting in a low accuracy of the evaluated shale hydrocarbon expulsion efficiency.

[0005] Embodiments of the present invention provide a method for evaluating shale hydrocarbon expulsion efficiency, including the following steps: Obtain a first core of shale by using the conventional core sampling method to obtain the hydrocarbon generation amount of shale through the first core; Obtain a second core of shale by using the pressure-maintaining core sampling method to obtain the water saturation rate, rock porosity and apparent rock density of shale; wherein, the water saturation rate, rock porosity and apparent rock density of the shale characterize the process of hydrocarbon migration and release in the fractures of shale; Obtain a crude oil sample in the second core and obtain the crude oil density of the crude oil sample; wherein, the crude oil sample contains various hydrocarbon compounds; Obtain the hydrocarbon content of shale according to the water saturation rate, rock porosity, apparent rock density and crude oil density of shale; Obtain the hydrocarbon expulsion efficiency of shale according to the hydrocarbon content and hydrocarbon generation amount of shale.

[0006] Preferably, the acquisition of the hydrocarbon generation amount of the shale includes: Obtain shale samples with different total organic carbon (TOC) content classifications, and select shale samples with TOC levels of 0.7%, 0.9%, 1.1%, 1.3%, 1.5%, 1.7%, 1.9%, and 2.1%. Under closed conditions, heat them to 600°C at heating rates of 20°C / min and 2°C / min respectively, and set three experimental temperature points on each shale sample, for a total of 24 experimental temperature points. Synchronously conduct the gold tube thermal simulation experiment to obtain the hydrocarbon generation amount of the shale samples at different vitrinite reflectance (Ro) values. Based on the hydrocarbon generation amount of the shale samples at different vitrinite reflectance (Ro) values, plot the hydrocarbon generation amount chart of the shale under different total organic carbon (TOC) classifications. Obtain the total organic carbon (TOC) content and vitrinite reflectance (Ro) of the first core. Locate the TOC curve corresponding to the first core in the hydrocarbon generation amount chart, and obtain the hydrocarbon generation amount of the shale according to the ordinate of the vitrinite reflectance (Ro) corresponding to the first core.

[0007] Preferably, the acquisition of the water saturation rate of the shale includes: During the process of obtaining the second core of the shale by pressure coring, continuously seal the core while continuously filling the wellbore with water to obtain the second core of the shale. Use a nuclear magnetic resonance instrument to scan the fresh second core obtained by pressure coring to obtain the original nuclear magnetic resonance T2 spectrum, and obtain the original water-bearing porosity according to the original nuclear magnetic resonance T2 spectrum. Saturate the second core with brine having the same salinity as the formation water, and use the nuclear magnetic resonance instrument to scan the second core again to obtain the saturated nuclear magnetic resonance T2 spectrum. Obtain the saturated water-bearing porosity according to the saturated nuclear magnetic resonance T2 spectrum. The water saturation rate of the shale is the ratio of the original water-bearing porosity to the saturated water-bearing porosity.

[0008] Preferably, the acquisition of the rock porosity and rock bulk density includes: Load the second core of the shale into a Dean Stark extraction instrument, select dichloromethane as the solvent, heat the solvent to evaporate the water in the core, collect the evaporated solvent, and after condensation, place the second core in a Soxhlet extractor to alternately perform the soaking and displacement processes to wash the oil in the core sample. Crush the second core after washing the oil to 20 mesh and dry it, and conduct density measurement to obtain the rock bulk density. After sealing the second core after washing the oil in the sample chamber, fill the reference chamber with helium gas at a pressure of 1.378 MPa, and conduct porosity measurement to obtain the rock porosity.

[0009] Preferably, the hydrocarbon content of the shale HThe acquisition method is as follows: ; Wherein: S W represents the water saturation rate; Φ represents the rock porosity; ρ r represents the apparent density of the rock; ρ o represents the density of crude oil.

[0010] Preferably, the hydrocarbon expulsion efficiency of the shale P The acquisition method is as follows: ; Wherein: H represents the hydrocarbon content of the shale; S represents the hydrocarbon generation amount of the shale.

[0011] An embodiment of the present invention further provides a shale hydrocarbon expulsion efficiency evaluation device, including: A shale measurement module, configured to obtain a first core of the shale by using the conventional core-taking method, so as to obtain the hydrocarbon generation amount of the shale through the first core; Obtain a second core of the shale by using the pressure-maintaining core-taking method, so as to obtain the water saturation rate, rock porosity and apparent density of the rock through the second core; wherein, the water saturation rate, rock porosity and apparent density of the shale characterize the migration and release process of hydrocarbons in the fractures of the shale; Obtain a crude oil sample in the second core and obtain the density of the crude oil in the crude oil sample; wherein, the crude oil sample contains various hydrocarbon compounds; A hydrocarbon expulsion efficiency determination module, configured to obtain the hydrocarbon content of the shale according to the water saturation rate, rock porosity, apparent density and crude oil density of the shale; Obtain the hydrocarbon expulsion efficiency of the shale according to the hydrocarbon content and hydrocarbon generation amount of the shale.

[0012] An embodiment of the present invention further provides an electronic device, including a memory and a processor; The memory is used to store a computer program; When the processor executes the computer program stored in the memory, the steps of a shale hydrocarbon expulsion efficiency evaluation method as described above are implemented.

[0013] An embodiment of the present invention further provides a computer-readable storage medium, configured to store a computer program, and when the computer program is executed by a processor, the steps of a shale hydrocarbon expulsion efficiency evaluation method as described above are implemented.

[0014] An embodiment of the present invention provides a shale hydrocarbon expulsion efficiency evaluation method, device, equipment and medium. Compared with the prior art, its beneficial effects are as follows: The present invention conducts hydrocarbon generation thermal simulation experiments on shale samples to obtain the hydrocarbon generation amounts of shale at different vitrinite reflectance (Ro), so as to construct hydrocarbon generation amount charts for shale under different total organic carbon (TOC) classifications; performs water saturation tests on core samples of shale to obtain the water saturation rates of the core samples; washes the core samples with oil and conducts porosity tests to obtain the rock porosity and the apparent density of the rock; obtains crude oil samples from the producing layers where the core samples are located and conducts crude oil physical property experiments to obtain the crude oil density; the present invention measures the water saturation rate, rock porosity, apparent density of the rock, and crude oil density of the core samples, and calculates the hydrocarbon content of the shale. In this process, by measuring the water saturation rate, rock porosity, and apparent density of the core, the release and migration of hydrocarbons in the fractures of the core during the hydrocarbon expulsion process are dynamically quantified, and the dynamic measurement process can realize the dynamic simulation of the hydrocarbon migration path, and finally achieve the accurate evaluation of the shale hydrocarbon expulsion efficiency. BRIEF DESCRIPTION OF THE DRAWINGS

[0015] Figure 1 FIG. is a schematic diagram of the overall process of a method for evaluating shale hydrocarbon expulsion efficiency provided by an embodiment of the present invention; Figure 2 FIG. is a schematic diagram of the hydrocarbon generation amount chart of shale with different TOC classifications in a method for evaluating shale hydrocarbon expulsion efficiency provided by an embodiment of the present invention; Figure 3 FIG. is a schematic diagram of the comparison of hydrocarbon generation amounts, hydrocarbon contents, and hydrocarbon expulsion efficiencies calculated from 9 typical shale oil drilling core samples in a method for evaluating shale hydrocarbon expulsion efficiency provided by an embodiment of the present invention. DETAILED DESCRIPTION OF THE EMBODIMENTS

[0016] In order to make the above objects, features, and advantages of the present invention more obvious and understandable, the following detailed description of the specific embodiments of the present invention will be made in conjunction with the accompanying drawings. Many specific details are set forth in the following description in order to fully understand the present invention. However, the present invention can be implemented in many other ways different from those described herein, and those skilled in the art can make similar improvements without departing from the connotation of the present invention. Therefore, the present invention is not limited by the specific embodiments disclosed below.

[0017] See Figure 1 , an embodiment of the present invention provides a method for evaluating shale hydrocarbon expulsion efficiency, including the following steps: Step 1: Select multiple sampling points in the field, obtain fresh samples within one meter under the outcrop in the field, conduct total organic carbon (TOC) test analysis on the samples to obtain the organic matter abundance levels of the samples, and the organic matter abundance levels are divided according to the organic matter content in the samples, and select the samples with low maturity.

[0018] Step 2: Select samples with TOC of 0.7%, 0.9%, 1.1%, 1.3%, 1.5%, 1.7%, 1.9%, and 2.1% from them for the gold tube thermal simulation experiment, obtain the hydrocarbon generation amounts at different Ro, and establish a hydrocarbon generation amount chart for shales with different TOC classifications, as Figure 2 shown.

[0019] Step 3: Through the fresh core samples after the cored section under pressure is taken out of the barrel, conduct in-situ water saturation tests on the spot to obtain the water saturation S of the core samples W .

[0020] Step 4: After washing the oil from the core samples obtained by coring under pressure, carry out helium porosity tests to obtain the rock porosity Φ and the apparent density ρ of the rock s .

[0021] Step 5: For the target formation crude oil samples obtained on the spot, conduct crude oil physical property experiments to obtain the crude oil density ρ o .

[0022] Step 6: Combine the water saturation S W , the rock porosity Φ, the apparent density ρ of the rock s , and the crude oil density ρ o to calculate the hydrocarbon capacity H of the rock.

[0023] The hydrocarbon capacity H of the rock is expressed as: .

[0024] Step 7: Conduct total organic carbon content TOC tests and kerogen vitrinite reflectance Ro analyses on the target core samples to obtain TOC and Ro. Find the corresponding TOC curve in the hydrocarbon generation rate chart of shales with different TOC classifications obtained in Step 2, read the ordinate corresponding to the response Ro, and obtain the hydrocarbon generation amount S of the shale.

[0025] Step 8: Combine the calculated hydrocarbon content H and the hydrocarbon generation amount S to finally calculate the hydrocarbon expulsion efficiency P of the shale.

[0026] The hydrocarbon expulsion efficiency P is expressed as: .

[0027] Specifically: Step 1: Select multiple sampling points in the field, obtain fresh samples one meter below the outcrop in the field, conduct TOC test analyses on the samples, obtain the organic matter abundance levels of the samples, and screen out the samples with low maturity.

[0028] Select multiple sampling points according to the actual situation. When sampling, select fresh samples about one meter below the outcrop in the field to avoid errors in sample testing. The organic matter abundance of the sample is obtained by measuring the total organic carbon (TOC): Crush the sample to obtain a sample powder with a mesh size of 200, wash off the inorganic carbon in the obtained sample with dilute hydrochloric acid, and then burn it in a high-temperature O 2 gas stream to obtain CO 2 content. Combining the corresponding relationship between the CO 2 content and the carbon content in the total organic carbon (TOC), the content of the total organic carbon (TOC) can be obtained.

[0029] Step 2: Select samples with TOC of 0.7%, 0.9%, 1.1%, 1.3%, 1.5%, 1.7%, 1.9%, and 2.1% for the gold tube thermal simulation experiment, obtain the hydrocarbon generation amounts at different Ro values, and establish a hydrocarbon generation amount chart for shales with different TOC grades, as Figure 2 shown.

[0030] The hydrocarbon generation amounts at different Ro values are obtained through the gold tube thermal simulation experiment: Select samples with regular TOC levels of 0.7%, 0.9%, 1.1%, 1.3%, 1.5%, 1.7%, 1.9%, and 2.1% from Step 1. Use the experimental instrument to heat up to 600°C at a heating rate of 20°C / min and 2°C / min respectively under closed conditions. There are a total of 24 experimental temperature points. After obtaining the hydrocarbon generation amounts at different Ro values, draw a hydrocarbon generation amount chart for shales with different TOC grades.

[0031] Step 3: Through the fresh core samples after the pressure-retaining coring section is taken out of the barrel, conduct on-site nuclear magnetic resonance method water saturation tests to obtain the water saturation S W .

[0032] The pressure-retaining coring technology is a method to obtain cores that maintain the integrity of reservoir fluids. By filling the corresponding tool with a sealing liquid before lowering it into the well and continuously sealing the core during the coring drilling process, it is possible to avoid the situation where the gas and light components in the crude oil in the core expand violently and escape due to the pressure reduction and temperature reduction when the core is taken from the bottom of the well to the ground.

[0033] The water saturation S W is obtained through nuclear magnetic resonance water saturation tests: Use a nuclear magnetic resonance instrument to scan the fresh core samples taken by pressure-retaining coring to obtain the nuclear magnetic resonance T2 spectrum, calculate the original water-bearing porosity, saturate the core samples with brine with the same salinity as the formation water, and conduct nuclear magnetic resonance T2 spectrum measurement again to calculate the saturated water-bearing porosity. The ratio of the two is the water saturation S W .

[0034] Step 4: After washing the core samples obtained by pressure-maintained coring to remove oil, measure the porosity by the helium method to obtain the rock porosity Φ and the apparent density ρ of the rock r 。

[0035] Before measuring the porosity of the samples, it is necessary to remove the original fluid in the core samples. The core is washed with oil by the distillation extraction method: The obtained dry core samples are loaded into a Dean Stark extraction instrument, dichloromethane is selected as the solvent, the solvent is heated to evaporate the water in the core, the evaporated solvent is collected, and after condensation, the core samples are put into a Soxhlet extractor, and the soaking and displacement processes are alternated to wash the oil. The distillation extraction takes more than 48 hours.

[0036] Rock porosity Φ and apparent density ρ of the rock r Obtained by the helium method porosity measurement method: The oil-washed samples are crushed to 20 mesh and dried, and the apparent density ρ of the rock is obtained according to GB / T 23561.3 r , after the sample is put into the sample chamber and sealed, helium with a pressure of about 1.378 MPa is filled into the reference chamber, and the rock porosity Φ is obtained according to GB / T 34533-2017.

[0037] Step 5: For the target formation crude oil samples obtained on-site, conduct crude oil physical property experiments to obtain the crude oil density ρ o 。

[0038] Step 6: Combine the water saturation S W , rock porosity Φ, apparent density ρ of the rock r and crude oil density ρ o , calculate the hydrocarbon capacity H per unit volume of rock, expressed as: 。

[0039] Among them, the apparent density of the rock is converted from ρ s to ρ r , indicating that its unit is converted from mg / m 3 to g / m 3 。

[0040] Step 7: Conduct total organic carbon content TOC tests and kerogen vitrinite reflectance Ro analyses on the target core samples to obtain TOC and Ro. Find the corresponding TOC curve in the hydrocarbon generation rate chart of different TOC-graded shales obtained in Step 2, read the ordinate corresponding to the response Ro, and obtain the hydrocarbon generation amount S of the shale.

[0041] The hydrocarbon generation amount S of the target shale is obtained by using the logging TOC and Ro data and combining with the hydrocarbon generation amount chart of shales with different TOC classifications obtained in Step 2: First, find the corresponding curve on the chart according to the TOC of the target core sample, and then correspond the Ro data of the target core sample to the abscissa of the chart to read the hydrocarbon generation amount S on the ordinate.

[0042] Step 8: Combine the calculated hydrocarbon content H and the hydrocarbon generation amount S to finally calculate the hydrocarbon expulsion efficiency P of the shale.

[0043] This invention includes eight steps: Step 1, obtain fresh field samples for TOC test analysis and screen out samples with low maturity; Step 2, select samples with TOC of 0.7%, 0.9%, 1.1%, 1.3%, 1.5%, 1.7%, 1.9%, and 2.1% from them for gold tube pyrolysis experiments to obtain the hydrocarbon generation amounts at different Ro values and establish the hydrocarbon generation amount charts of shales with different TOC classifications; Step 3, collect fresh core samples on-site after the cored well section is taken out of the barrel for water saturation test to obtain the water saturation S W ; Step 4, wash the core samples with oil and then conduct porosity tests to obtain the rock porosity Φ and the bulk density ρ of the rock s ; Step 5, conduct crude oil physical property experiments on the crude oil samples of the target pay zone to obtain the crude oil density ρ o ; Step 6, combine the water saturation, rock porosity, bulk density of the rock, and crude oil density to calculate the hydrocarbon content H of the rock; Step 7, conduct TOC and kerogen vitrinite reflectance tests on the core samples to obtain the organic carbon content TOC and the vitrinite reflectance Ro, and obtain the hydrocarbon generation amount of the shale by referring to the hydrocarbon production rate charts of shales with different TOC levels; Step 8, combine the hydrocarbon content and the hydrocarbon generation amount to calculate the hydrocarbon expulsion efficiency.

[0044] This invention calculates the hydrocarbon expulsion efficiency of shales based on the volumetric method, optimizes the quantification process of the hydrocarbon expulsion efficiency, improves the deficiencies of the existing methods in hydrocarbon expulsion efficiency evaluation, enhances the accuracy of shale oil and gas resource potential evaluation, and provides reliable technical support for unconventional oil and gas exploration and development. By constructing the hydrocarbon generation amount charts of shales with different TOC through pyrolysis experiments and combining key parameters such as the water saturation, porosity, crude oil density, and organic carbon content of on-site core samples, the hydrocarbon content and hydrocarbon generation amount of the rock are quantitatively calculated, and finally the accurate evaluation of the hydrocarbon expulsion efficiency is realized. This invention makes up for the deficiencies of the existing technology in the lack of systematicness and comprehensiveness in hydrocarbon expulsion efficiency calculation, and provides a reliable basis for the scientific evaluation of shale oil and gas resources and reservoir selection.

[0045] The above-described embodiments merely represent several implementation manners of the present invention. The description thereof is relatively specific and detailed, but it should not be construed as a limitation on the scope of the invention patent. It should be noted that for those of ordinary skill in the art, without departing from the concept of the present invention, several modifications and improvements can still be made, and these all fall within the protection scope of the present invention. Therefore, the protection scope of the present invention patent shall be subject to the appended claims.

Claims

1. A method for evaluating shale hydrocarbon expulsion efficiency, characterized in that: The following steps are involved: A first core of the shale is obtained by a conventional coring method, so as to obtain the hydrocarbon generation amount of the shale through the first core; A second core of shale is obtained by using a pressure-maintaining coring method, so as to obtain the water saturation, rock porosity and rock apparent density of the shale through the second core; wherein the water saturation, rock porosity and rock apparent density of the shale characterize the migration and release process of hydrocarbons in the cracks of the shale; Obtaining a crude oil sample in the second core, and obtaining a crude oil density of the crude oil sample; wherein the crude oil sample contains a plurality of hydrocarbon compounds; The hydrocarbon content of shale is obtained based on the water saturation, rock porosity, rock apparent density and crude oil density of shale; The hydrocarbon expulsion efficiency of shale is obtained based on the hydrocarbon content and hydrocarbon generation amount of shale.

2. A shale hydrocarbon expulsion efficiency evaluation method according to claim 1, characterized in that: The acquisition of the hydrocarbon generation amount of the shale comprises: Obtain shale samples with different TOC levels, and select shale samples with TOC levels of 0.7%, 0.9%, 1.1%, 1.3%, 1.5%, 1.7%, 1.9%, and 2.1%. Under closed conditions, heat the temperature to 600°C at a rate of 20°C / min and 2°C / min, respectively. Set three experimental temperature points on each shale sample, for a total of 24 experimental temperature points, and conduct gold tube thermal simulation experiments simultaneously to obtain the hydrocarbon generation amount of shale samples under different vitrinite reflectance Ro. According to the hydrocarbon generation amount of shale samples under different vitrinite reflectance Ro, a chart of hydrocarbon generation amount of shale under different total organic carbon TOC classification is drawn; The total organic carbon content TOC and the vitrinite reflectance Ro of the first core are obtained, the total organic carbon content TOC curve corresponding to the first core is found in the hydrocarbon generation amount chart, and the hydrocarbon generation amount of the shale is obtained according to the ordinate of the vitrinite reflectance Ro corresponding to the first core.

3. A shale hydrocarbon expulsion efficiency evaluation method according to claim 1, characterized in that: The acquisition of the water saturation of the shale includes: In the process of obtaining the second core of shale by pressure-maintaining coring, when the well is continuously filled with water, the core is continuously enclosed to obtain the second core of shale; The fresh second core sampled under pressure is scanned using a nuclear magnetic resonance instrument to obtain an original nuclear magnetic resonance T2 spectrum, and the original water-containing porosity is obtained according to the original nuclear magnetic resonance T2 spectrum; The second core was saturated with brine consistent with the mineralization of formation water, and the second core was scanned again with a nuclear magnetic resonance instrument to obtain a saturated nuclear magnetic resonance T2 spectrum. The saturated water-containing porosity was obtained based on the saturated nuclear magnetic resonance T2 spectrum. The water saturation rate of shale is the ratio of the original water-containing porosity to the saturated water-containing porosity.

4. A shale hydrocarbon expulsion efficiency evaluation method according to claim 1, characterized in that: The rock porosity and rock apparent density are obtained by: The second core of the shale is placed in the Dean Stark extraction apparatus, dichloromethane is selected as the solvent, the solvent is heated to evaporate the water in the core, the evaporated solvent is collected, and after condensation, the second core is placed in the Soxhlet extractor, and the soaking and drainage processes are alternately performed to clean the oil in the core sample; The second core after oil washing was crushed to 20 mesh and dried, and the density was measured to obtain the apparent density of the rock; After the second core after oil washing is placed in the sample chamber and sealed, helium with a pressure of 1.378 MPa is filled into the reference chamber to measure the porosity and obtain the rock porosity.

5. The method for evaluating shale hydrocarbon expulsion efficiency according to claim 1, characterized in that: The hydrocarbon content of the shale H The way to obtain is: ； in: S W represents water saturation; Φ represents rock porosity; ρ r represents the apparent density of rock; ρ o Represents the density of crude oil.

6. A shale hydrocarbon expulsion efficiency evaluation method according to claim 5, characterized in that: The hydrocarbon expulsion efficiency of the shale P The way to obtain is: ； in: H Indicates the hydrocarbon content of shale; S Indicates the hydrocarbon generation amount of shale.

7. A shale hydrocarbon expulsion efficiency evaluation device, characterized in that: include: A shale measurement module, used for obtaining a first core of shale by a conventional coring method, so as to obtain the hydrocarbon generation amount of the shale through the first core; A second core of shale is obtained by using a pressure-maintaining coring method, so as to obtain the water saturation, rock porosity and rock apparent density of the shale through the second core; wherein the water saturation, rock porosity and rock apparent density of the shale characterize the migration and release process of hydrocarbons in the cracks of the shale; Obtaining a crude oil sample in the second core, and obtaining a crude oil density of the crude oil sample; wherein the crude oil sample contains a plurality of hydrocarbon compounds; The hydrocarbon expulsion efficiency determination module is used to obtain the hydrocarbon content of the shale based on the water saturation, rock porosity, rock apparent density and crude oil density of the shale; The hydrocarbon expulsion efficiency of shale is obtained based on the hydrocarbon content and hydrocarbon generation amount of shale.

8. An electronic device, characterized in that: include: Memory and processor; The memory is used to store computer programs; The processor is used to implement the steps of a shale hydrocarbon expulsion efficiency evaluation method as described in any one of claims 1 to 6 when executing the computer program stored in the memory.

9. A computer-readable storage medium, characterized in that: Used to store a computer program, which, when executed by a processor, implements the steps of a shale hydrocarbon expulsion efficiency evaluation method as described in any one of claims 1 to 6.

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