Shale oil reservoir pore structure correction method, device, equipment and medium

Abstract

The application provides a shale oil reservoir pore structure correction method, device, equipment and medium; relates to the pore structure correction technical field, and the method comprises the steps of: carrying out nuclear magnetic resonance test on the first shale to obtain one-dimensional nuclear magnetic T2 spectrum and two-dimensional nuclear magnetic T1-T2 spectrum of the first shale; T1 represents longitudinal relaxation time, and T2 represents transverse relaxation time; identifying the one-dimensional nuclear magnetic T2 spectrum to obtain the first signal amplitude of the first shale; identifying the two-dimensional nuclear magnetic T1-T2 spectrum to obtain the second signal amplitude of the first shale; the correlation between the first signal amplitude and the second signal amplitude is established; the correlation is used to determine the amplitude conversion relationship of the one-dimensional nuclear magnetic T2 spectrum and the two-dimensional nuclear magnetic T1-T2 spectrum corresponding to the skeleton signal of the first shale; based on the amplitude conversion relationship, the one-dimensional nuclear magnetic T2 spectrum and the two-dimensional nuclear magnetic T1-T2 spectrum of the target shale under the saturated state, the pore structure of the target shale to be corrected is corrected. In this way, the nuclear magnetic porosity and pore size distribution of the shale oil reservoir can be accurately determined.

Description

Technical Field

[0001] This application relates to the field of pore structure correction technology, and in particular to a method, apparatus, equipment and medium for pore structure correction of shale oil reservoirs. Background Technology

[0002] Characterizing the pore structure of shale oil reservoirs is crucial for exploration and development. To obtain accurate pore characteristics, current methods often employ high-temperature, high-pressure washing and drying to remove pore fluids, followed by saturated fluid and NMR testing. However, this method has significant drawbacks: firstly, for particularly dense shale oil reservoirs, pore fluids are difficult to completely remove, and residual fluids interfere with NMR signals, leading to lower porosity test results and discontinuous T2 NMR readings; secondly, washing requires toxic organic reagents and is conducted under high temperature and pressure, which can easily damage the shale, causing measurement errors and alterations to the pore structure. Therefore, current methods cannot accurately determine the NMR porosity and pore size distribution of shale oil reservoirs. Summary of the Invention

[0003] This application provides a method, apparatus, equipment, and medium for correcting the pore structure of shale oil reservoirs to solve one or more problems existing in related technologies.

[0004] According to a first aspect of this application, a method for correcting the pore structure of a shale oil reservoir is provided, comprising: performing nuclear magnetic resonance (NMR) testing on a first shale to obtain a one-dimensional NMR T2 spectrum and a two-dimensional NMR T1-T2 spectrum of the first shale; T1 representing the longitudinal relaxation time and T2 representing the transverse relaxation time; identifying the one-dimensional NMR T2 spectrum to obtain a first signal amplitude of the first shale; identifying the two-dimensional NMR T1-T2 spectrum to obtain a second signal amplitude of the first shale; establishing a correlation between the first signal amplitude and the second signal amplitude; the correlation is used to determine the amplitude conversion relationship between the one-dimensional NMR T2 spectrum and the two-dimensional NMR T1-T2 spectrum signal corresponding to the skeleton signal of the first shale; and correcting the pore structure of the target shale based on the amplitude conversion relationship and the one-dimensional NMR T2 spectrum and the two-dimensional NMR T1-T2 spectrum of the target shale under saturation.

[0005] According to one embodiment of this application, the correlation between the first signal amplitude and the second signal amplitude is expressed by the following formula:

[0006]

[0007] in, Indicates the amplitude of the second signal. Indicates the amplitude of the first signal. α The correlation coefficient between the amplitude of the first signal and the amplitude of the second signal. βThis refers to the signal amplitude of the fluid component within the first signal amplitude of the first shale;

[0008] The amplitude conversion relationship between the one-dimensional NMR T2 spectrum and the two-dimensional NMR T1-T2 spectrum corresponding to the skeleton signal of the first shale is as follows:

[0009]

[0010] in, This represents the amplitude of the one-dimensional nuclear magnetic resonance T2 spectrum signal corresponding to the skeleton signal of the first shale.

[0011] According to one embodiment of this application, the correction of the pore structure of the target shale under saturation based on the amplitude conversion relationship and the one-dimensional NMR T2 spectrum and two-dimensional NMR T1-T2 spectrum of the target shale under saturation includes:

[0012] Nuclear magnetic resonance (NMR) tests were performed on the target shale to be corrected under saturation conditions to obtain the one-dimensional NMR T2 spectrum and the two-dimensional NMR T1-T2 spectrum of the target shale to be corrected.

[0013] The two-dimensional nuclear magnetic resonance T1-T2 spectrum of the target shale to be corrected is identified to obtain the second signal amplitude of the target saturated shale under saturated conditions.

[0014] The one-dimensional nuclear magnetic resonance T2 spectrum of the target shale to be corrected is identified to obtain the total signal amplitude of the target shale to be corrected;

[0015] Based on the amplitude conversion relationship and the second signal amplitude of the target shale under saturation, the amplitude of the first signal one-dimensional nuclear magnetic solid skeleton signal of the target shale under saturation is determined.

[0016] Based on the first signal amplitude and the total signal amplitude of the one-dimensional nuclear magnetic resonance solid skeleton signal of the target shale under saturation, a third signal amplitude is determined; the third signal amplitude characterizes the pore fluid signal amplitude of the target shale.

[0017] The pore structure of the target shale is corrected based on the amplitude of the third signal, the amplitude of the one-dimensional NMR solid framework signal of the target shale to be corrected, and the amplitude of the third signal of the one-dimensional NMR T2 spectrum.

[0018] According to one embodiment of this application, the correction of the pore structure of the target shale based on the third signal amplitude, the one-dimensional NMR solid-state framework signal amplitude of the target shale to be corrected, and the one-dimensional NMR T2 spectrum includes:

[0019] Based on the amplitude of the third signal, the fluid mass and fluid density in the pores of the target shale to be corrected under saturation, the porosity of the target shale to be corrected is corrected.

[0020] Based on the one-dimensional NMR solid-state framework signal amplitude of the target shale to be corrected, the third signal amplitude of the one-dimensional NMR solid-state framework signal of the target shale to be corrected, and the one-dimensional NMR T2 spectrum of the target shale to be corrected under saturation, the pore size distribution of the target shale to be corrected is corrected.

[0021] According to one embodiment of this application, the step of correcting the porosity of the target shale to be corrected based on the amplitude of the third signal, the fluid mass and fluid density in the pores of the target shale under saturation includes:

[0022] Determine the conversion factor between signal amplitude and fluid mass;

[0023] Based on the conversion coefficient and the amplitude of the third signal, the fluid mass in the pores of the target shale to be corrected under saturation is determined.

[0024] Based on the fluid mass and the fluid density, the fluid volume in the pores of the target shale to be corrected under saturated conditions is determined;

[0025] The porosity of the target shale to be corrected is determined based on the fluid volume and the shale volume of the target shale to be corrected.

[0026] According to one embodiment of this application, the correction of the pore size distribution of the target shale to be corrected based on the one-dimensional NMR solid-state framework signal amplitude and the one-dimensional NMR T2 spectrum of the target shale to be corrected under saturation includes:

[0027] Gaussian distribution peak fitting was performed on the one-dimensional nuclear magnetic resonance (NMR) T2 spectrum of the target shale under saturation to obtain the signal distribution of the P1 peak in the one-dimensional NMR T2 spectrum; the P1 peak characterizes the rock skeleton and part of the fluid distribution.

[0028] Based on the second signal amplitude of the target shale to be corrected and the amplitude conversion relationship between the one-dimensional NMR and two-dimensional NMR solid skeleton signals, the amplitude of the one-dimensional NMR skeleton signal of the target shale to be corrected is determined;

[0029] Based on the amplitude of the one-dimensional NMR skeleton signal, the amplitude in the signal distribution of the P1 peak is replaced to obtain the one-dimensional NMR skeleton signal distribution.

[0030] Subtracting the one-dimensional NMR T2 spectrum of the target shale under saturation from the one-dimensional NMR skeleton signal distribution yields the one-dimensional NMR T2 spectrum characterizing the pore size distribution of the target shale.

[0031] According to one embodiment of this application, determining the amplitude of the one-dimensional NMR skeleton signal of the target shale to be corrected based on the second signal amplitude of the target shale to be corrected and the amplitude conversion relationship between the one-dimensional NMR and two-dimensional NMR solid-state skeleton signals includes:

[0032] The amplitude of the one-dimensional NMR skeleton signal of the target shale to be corrected is calculated based on the following formula:

[0033]

[0034] in, This represents the geometric peak area of ​​the one-dimensional NMR skeleton signal distribution of the target shale to be corrected. 7 represents the amplitude of the one-dimensional NMR skeleton signal of the target shale to be corrected; 7 represents the logarithmic geometric length of the one-dimensional NMR T2 distribution from 0.001ms to 10000ms; and 200 represents the number of one-dimensional NMR T2 spectral points.

[0035] According to a second aspect of this application, a shale oil reservoir pore structure correction device is provided, characterized in that it comprises:

[0036] The testing module is used to perform nuclear magnetic resonance (NMR) tests on the first shale to obtain the one-dimensional NMR T2 spectrum and the two-dimensional NMR T1-T2 spectrum of the first shale; T1 represents the longitudinal relaxation time and T2 represents the transverse relaxation time.

[0037] The first identification module is used to identify the one-dimensional nuclear magnetic resonance T2 spectrum to obtain the first signal amplitude of the first shale;

[0038] The second identification module is used to identify the two-dimensional nuclear magnetic resonance T1-T2 spectrum to obtain the second signal amplitude of the first shale;

[0039] A module is established to establish a correlation between the amplitude of the first signal and the amplitude of the second signal; the correlation is used to determine the amplitude conversion relationship between the one-dimensional NMR T2 spectrum and the two-dimensional NMR T1-T2 spectrum corresponding to the skeleton signal of the first shale.

[0040] The correction module is used to correct the pore structure of the target shale based on the amplitude conversion relationship, the one-dimensional NMR T2 spectrum and the two-dimensional NMR T1-T2 spectrum of the target shale under saturation.

[0041] According to a third aspect of this application, an electronic device is provided, comprising: at least one processor; and a memory communicatively connected to the at least one processor; wherein the memory stores instructions executable by the at least one processor, the instructions being executed by the at least one processor to enable the at least one processor to perform the method described in this application.

[0042] According to a fourth aspect of this application, a non-transitory computer-readable storage medium is provided storing computer instructions for causing the computer to perform the methods described in this application.

[0043] The method in this embodiment involves performing nuclear magnetic resonance (NMR) testing on a first shale to obtain a one-dimensional NMR T2 spectrum and a two-dimensional NMR T1-T2 spectrum. T1 represents the longitudinal relaxation time, and T2 represents the transverse relaxation time. The one-dimensional NMR T2 spectrum is identified to obtain a first signal amplitude of the first shale. The two-dimensional NMR T1-T2 spectrum is also identified to obtain a second signal amplitude of the first shale. A correlation is established between the first signal amplitude and the second signal amplitude. This correlation is used to determine the amplitude conversion relationship between the one-dimensional NMR T2 spectrum and the two-dimensional NMR T1-T2 spectrum corresponding to the skeleton signal of the first shale. Based on the conversion relationship and the one-dimensional NMR T2 spectrum and two-dimensional NMR T1-T2 spectrum of the target shale under saturation, the pore structure of the target shale is corrected. This allows for accurate determination of the NMR porosity and pore size distribution of shale oil reservoirs.

[0044] It should be understood that the teachings of this application are not required to achieve all the beneficial effects described above, but rather that a specific technical solution can achieve a specific technical effect, and other embodiments of this application can also achieve beneficial effects not mentioned above. Attached Figure Description

[0045] The above and other objects, features, and advantages of exemplary embodiments of this application will become readily apparent from the following detailed description taken in conjunction with the accompanying drawings. Several embodiments of this application are illustrated in the drawings by way of example and not limitation, in which:

[0046] In the accompanying drawings, the same or corresponding reference numerals indicate the same or corresponding parts.

[0047] Figure 1 This illustration shows a flowchart of the shale oil reservoir pore structure correction method provided in an embodiment of this application. Figure 1 ;

[0048] Figure 2 This illustration shows a flowchart of the shale oil reservoir pore structure correction method provided in an embodiment of this application. Figure 2 ;

[0049] Figure 3 This illustration shows a flowchart of the shale oil reservoir pore structure correction method provided in an embodiment of this application. Figure 3 ;

[0050] Figure 4This application illustrates a scenario where the shale oil reservoir pore structure correction method provided in this embodiment is used. Figure 1 ;

[0051] Figure 5 This application illustrates a scenario where the shale oil reservoir pore structure correction method provided in this embodiment is used. Figure 2 ;

[0052] Figure 6 This application illustrates a scenario where the shale oil reservoir pore structure correction method provided in this embodiment is used. Figure 3 ;

[0053] Figure 7 This application illustrates a scenario where the shale oil reservoir pore structure correction method provided in this embodiment is used. Figure 4 ;

[0054] Figure 8 This application illustrates a scenario where the shale oil reservoir pore structure correction method provided in this embodiment is used. Figure 5 ;

[0055] Figure 9 This application illustrates a scenario where the shale oil reservoir pore structure correction method provided in this embodiment is used. Figure 6 ;

[0056] Figure 10 This illustration shows an optional schematic diagram of the shale oil reservoir pore structure correction device provided in an embodiment of this application;

[0057] Figure 11 A schematic diagram of the composition structure of the electronic device provided in the embodiments of this application is shown. Detailed Implementation

[0058] To make the objectives, features, and advantages of this application more apparent and understandable, the technical solutions in the embodiments of this application will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this application, and not all embodiments. Based on the embodiments of this application, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this application.

[0059] In the following description, references are made to “some embodiments,” which describe a subset of all possible embodiments. However, it is understood that “some embodiments” may be the same subset or different subsets of all possible embodiments and may be combined with each other without conflict.

[0060] In the following description, the terms "first" and "second" are used merely to distinguish similar objects and do not represent a specific ordering of objects. It is understood that "first" and "second" may be interchanged in a specific order or sequence where permitted, so that the embodiments of this application described herein can be implemented in an order other than that illustrated or described herein.

[0061] Unless otherwise defined, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs. The terminology used herein is for the purpose of describing embodiments of this application only and is not intended to limit this application.

[0062] The processing flow of the shale oil reservoir pore structure correction method provided in the embodiments of this application is described. See [link to relevant documentation]. Figure 1 , Figure 1 This is a schematic diagram of the processing flow of the shale oil reservoir pore structure correction method provided in the embodiments of this application. Figure 1 , will combine Figure 1 Steps S101-S105 are explained below.

[0063] Step S101: Perform nuclear magnetic resonance (NMR) testing on the first shale to obtain the one-dimensional NMR T2 spectrum and the two-dimensional NMR T1-T2 spectrum of the first shale; T1 represents the longitudinal relaxation time and T2 represents the transverse relaxation time.

[0064] In some embodiments, the first shale can be in its original state, washed-oil-dried state, or saturated state. The first shale can be the shale sample corresponding to the core. Specifically, the core is taken from the Arshan 4th Member (A4 Member) shale oil system in the Erlian Basin's Errennaoer Depression. After core extraction (i.e., in its original state), the shale is processed using waterless cutting to create a regular shape for easy volume measurement (either a cylinder or a cube). In this embodiment, the first shale can be processed into a circular plunger sample with a diameter of approximately 25 mm and a length of approximately 20 mm. Before conducting nuclear magnetic resonance (NMR) testing, the geometric parameters of the circular plunger sample are measured, including diameter and height, and the sample volume is calculated based on the diameter and height. The original circular plunger sample is vacuum-dried at 105°C to obtain a circular plunger sample in the washed-oil-dried state. One-dimensional and two-dimensional NMR tests are performed on the circular plunger sample in the washed-oil-dried state, and the sample is weighed. Subsequently, the sample is vacuum-dried for more than 24 hours and pressurized at 10 MPa to saturate with n-dodecane for 48 hours to obtain a saturated circular plunger sample. The saturated circular plunger sample was subjected to one-dimensional and two-dimensional NMR tests and weighed. The NMR tests were performed using a MesoMR12-060H-I NMR spectrometer manufactured by Newmax Corporation of Suzhou, Jiangsu Province, China. The measured resonance frequency was approximately 12 MHz, and the magnetic field strength was 0.3 T ± 0.05 T. The T1-T2 test used a saturation-recovery-Carr-Purcell-Meiboom-Gill (SR-CPMG) pulse sequence with the following parameters: wait time (TW) of 3000 ms, number of stacks (NS) of 32, number of echoes (NECH) of 4096, and echo interval of 0.07 ms. Thus, the one-dimensional T2 NMR spectrum and the two-dimensional T1-T2 NMR spectrum of the circular plunger sample were obtained, where T1 represents the longitudinal relaxation time and T2 represents the transverse relaxation time.

[0065] Step S102: Identify the one-dimensional nuclear magnetic resonance T2 spectrum to obtain the first signal amplitude of the first shale.

[0066] In some embodiments, the one-dimensional NMR T2 spectrum is identified according to a pre-defined integration region or through a peak identification algorithm to obtain the signal region corresponding to the first shale that is related to the framework signal and some fluid signals. The area of ​​this region is calculated to obtain the first signal amplitude. Specifically, the peak area of ​​the P1 peak in the one-dimensional NMR T2 spectrum of the first shale under the washed oil drying state is obtained, and the first signal amplitude is determined based on the peak area of ​​the P1 peak. The P1 peak can reflect the framework signal and some fluid signals corresponding to the first shale. Wherein, if the first shale is thoroughly washed and dried, there is no fluid signal, and the P1 peak can reflect the framework signal corresponding to the first shale. If the first shale is not thoroughly washed and dried, the P1 peak can reflect the framework signal and (possibly) some fluid signals corresponding to the first shale.

[0067] Step S103: Identify the two-dimensional nuclear magnetic resonance T1-T2 spectrum to obtain the second signal amplitude of the first shale.

[0068] In some embodiments, regions containing skeletal signals are selected based on the T1 and T2 time ranges on the two-dimensional nuclear magnetic resonance (NMR) T1-T2 spectrum of the first shale in the washed-oil-dried state. The second signal amplitude is obtained by integrating these regions using the two-dimensional spectral integration method. Specifically, the regions containing skeletal signals and various fluid signals in the first shale are identified based on the two-dimensional NMR T1-T2 spectrum. These fluid signals may include pore-bound water, pore-adsorbed oil, pore-bound oil, mobile oil, and mobile water, etc. The skeletal signals remain unchanged during drying and saturation. However, due to incomplete drying or washing conditions, fluid residues exist in the first shale in the washed-oil-dried state. The second signal amplitude is obtained by integrating the regions containing skeletal signals using the two-dimensional spectral integration method.

[0069] Step S104: Establish the correlation between the amplitude of the first signal and the amplitude of the second signal; the correlation is used to determine the amplitude conversion relationship between the one-dimensional NMR T2 spectrum and the two-dimensional NMR T1-T2 spectrum corresponding to the skeleton signal of the first shale.

[0070] In some embodiments, the identified first signal amplitude and second signal amplitude are imported into data processing software, and a linear regression analysis method is used to establish a linear equation between the first signal amplitude and the second signal amplitude. The slope of the linear equation is the signal amplitude conversion relationship of the skeleton signal of the first shale in the two spectra, and the intercept represents the fluid signal in the first signal amplitude.

[0071] Step S105: Based on the amplitude conversion relationship and the one-dimensional NMR T2 spectrum and two-dimensional NMR T1-T2 spectrum of the target shale under saturation, the pore structure of the target shale is corrected.

[0072] In some embodiments, the target shale to be corrected may include: shale samples that are not washed with oil or are incompletely washed with oil, and whose pore structure and fluid distribution characteristics require correction. The correction process may include porosity correction and pore size distribution correction, wherein porosity correction refers to recalculating the porosity of shale under saturated conditions through an established transformation relationship. Pore size distribution correction refers to using nuclear magnetic resonance spectroscopy processing methods to remove interference from the framework signal to obtain a more realistic pore size distribution.

[0073] The method of this application, by establishing the amplitude conversion relationship between the two-dimensional NMR T1-T2 spectrum and the one-dimensional NMR T2 spectrum of the skeleton signal, solves the problems of incomplete oil washing leading to low porosity test results and discontinuous pore size distribution in current methods. This method eliminates the need for oil washing; it directly performs saturated one-dimensional and two-dimensional NMR tests on the original shale to obtain accurate porosity and pore size distribution information. This effectively prevents the damage to the shale pore structure, time consumption, material consumption, and health hazards to laboratory personnel caused by oil washing. By establishing the amplitude conversion relationship between the two-dimensional NMR T1-T2 spectrum and the one-dimensional NMR T2 spectrum of the skeleton signal, the porosity and pore size distribution of shale can be accurately obtained, effectively eliminating the influence of solid hydrogen nuclei in shale, obtaining more realistic shale pore characteristics, and achieving accurate characterization of the porosity and pore size distribution of shale oil reservoirs. The method of this application can be widely applied to other strata or regions, achieving accurate porosity and pore size distribution information without oil washing, simply by performing saturated one-dimensional and two-dimensional NMR tests on the original shale. This significantly shortens the experimental cycle and improves experimental efficiency, facilitating large-scale application on offshore platforms or in remote mining areas, thereby enhancing the efficiency and accuracy of shale oil exploration and development. It avoids the use of toxic organic reagents and high-temperature, high-pressure operations, reducing the risk of volatile toxic gas leaks and potential equipment explosions during experiments, thus protecting the health of experimental personnel.

[0074] In some embodiments, the correlation between the first signal amplitude and the second signal amplitude in step S104 is expressed by the following formula:

[0075]

[0076] in, Indicates the amplitude of the second signal. Indicates the amplitude of the first signal. α The correlation coefficient between the amplitude of the first signal and the amplitude of the second signal. β This refers to the signal amplitude of the fluid component within the first signal amplitude of the first shale.

[0077] The amplitude conversion relationship between the one-dimensional NMR T2 spectrum and the two-dimensional NMR T1-T2 spectrum corresponding to the skeleton signal of the first shale is as follows:

[0078]

[0079] in, This represents the amplitude of the one-dimensional nuclear magnetic resonance T2 spectrum signal corresponding to the skeleton signal of the first shale.

[0080] In some embodiments, the processing flow of the shale oil reservoir pore structure correction method is illustrated. Figure 2 ,like Figure 2As shown, step S105, which involves correcting the pore structure of the target shale based on the amplitude conversion relationship and the one-dimensional NMR T2 spectrum and two-dimensional NMR T1-T2 spectrum of the target shale under saturation, may include:

[0081] Step S201: Perform nuclear magnetic resonance (NMR) testing on the target shale to be corrected under saturation to obtain the one-dimensional NMR T2 spectrum and the two-dimensional NMR T1-T2 spectrum of the target shale to be corrected.

[0082] Step S202: Identify the two-dimensional nuclear magnetic resonance T1-T2 spectrum of the target shale to be corrected, and obtain the second signal amplitude of the target shale under saturation.

[0083] Step S203: Identify the one-dimensional nuclear magnetic resonance T2 spectrum of the target shale to be corrected to obtain the total signal amplitude of the target shale to be corrected.

[0084] In this embodiment, the one-dimensional NMR T2 spectrum under saturation can include: a spectrum reflecting the transverse relaxation time distribution obtained by NMR testing of the target shale after its pores are saturated with fluid. The two-dimensional NMR T1-T2 spectrum under saturation can include: a spectrum simultaneously reflecting the longitudinal and transverse relaxation time relationships obtained by NMR testing of the target shale after its pores are saturated with fluid. The total signal amplitude can include: the sum of the intensities of all signals in the one-dimensional NMR T2 spectrum.

[0085] Step S204: Based on the amplitude conversion relationship and the second signal amplitude of the target shale to be corrected in the saturated state, determine the one-dimensional nuclear magnetic solid skeleton signal amplitude of the target shale to be corrected in the saturated state.

[0086] In this embodiment, based on the correlation between the first signal amplitude and the second signal amplitude, the amplitude conversion relationship between the one-dimensional and two-dimensional NMR amplitudes of the skeleton can be determined as follows: Substituting the second signal amplitude of the target shale under saturation into the aforementioned amplitude conversion relationship, the one-dimensional NMR solid-state framework signal amplitude of the target shale under saturation is calculated. It is a constant.

[0087] Step S205: Determine the third signal amplitude based on the one-dimensional NMR solid-state skeleton signal amplitude and total signal amplitude of the target shale under saturation.

[0088] In this embodiment, step S205 can be represented by the following formula.

[0089]

[0090] in, S fluid-1DThe third signal amplitude characterizes the pore fluid signal amplitude in the one-dimensional NMR T2 spectrum of the target shale to be corrected; S total-1D This represents the total signal amplitude. The amplitude of the one-dimensional NMR solid-state framework signal; S ps-1D , and S fluid-1D The units are all au / g.

[0091] Step S206: Based on the amplitude of the third signal, the amplitude of the one-dimensional NMR solid framework signal of the target shale to be corrected, and the one-dimensional NMR T2 spectrum, the pore structure of the target shale to be corrected is corrected.

[0092] As an example, nuclear magnetic resonance (NMR) testing was performed on the target shale to be corrected under saturation conditions to obtain its one-dimensional NMR T2 spectrum and two-dimensional NMR T1-T2 spectrum. By identifying the two-dimensional NMR T1-T2 spectrum of the target shale to be corrected, the second signal amplitude under saturation conditions was extracted. Simultaneously, the one-dimensional NMR T2 spectrum of the target shale to be corrected was identified to obtain the total signal amplitude of the target shale to be corrected. Based on the correlation between the first and second signal amplitudes, the amplitude conversion relationship between one-dimensional and two-dimensional NMR of the solid framework signal can be determined as follows: The second signal amplitude of the target shale under saturation was substituted into the aforementioned amplitude conversion relationship to calculate the one-dimensional NMR framework signal amplitude of the target shale. Then, the one-dimensional NMR framework signal amplitude was subtracted from the total signal amplitude to obtain the third signal amplitude, which characterizes the pore fluid signal amplitude of the target shale. Finally, based on the third signal amplitude, the one-dimensional NMR solid framework signal amplitude, and the one-dimensional NMR T2 spectrum under saturation, the pore structure of the target shale was corrected, including corrections to porosity and pore size distribution, to evaluate the pore structure characteristics of the target shale.

[0093] In some embodiments, the processing flow of the shale oil reservoir pore structure correction method is illustrated. Figure 3 ,like Figure 3 As shown, step S206, which corrects the pore structure of the target shale based on the third signal amplitude, the one-dimensional NMR solid framework signal amplitude, and the one-dimensional NMR T2 spectrum, may specifically include:

[0094] Step S301: Based on the amplitude of the third signal, the fluid mass and fluid density in the pores of the target shale to be corrected under saturation, the porosity of the target shale to be corrected is corrected.

[0095] In some embodiments, step S301 may include: determining a conversion coefficient between signal amplitude and fluid mass; determining the fluid mass in the pores of the target shale to be corrected under saturated conditions based on the conversion coefficient and the third signal amplitude; determining the fluid volume in the pores of the target shale to be corrected under saturated conditions based on the fluid mass and fluid density; and determining the porosity of the target shale to be corrected based on the fluid volume and the shale volume of the target shale to be corrected.

[0096] In some embodiments, the conversion coefficient may include a proportionality constant between the signal amplitude and the fluid mass. Specifically, a linear regression analysis method can be used to establish a linear equation between the one-dimensional NMR signal amplitude and the saturated mass to obtain the proportionality constant. The fluid mass may include the fluid mass in the pores of the target shale to be corrected under saturated conditions. The fluid density may include the saturated fluid density. The fluid volume may include the fluid volume in the pores of the target shale to be corrected under saturated conditions. The shale volume may include the geometric volume of the target shale to be corrected.

[0097] In this embodiment, the fluid mass in the pores of the target shale to be corrected under saturated conditions is determined based on the conversion coefficient and the amplitude of the third signal, which can be expressed by the following formula.

[0098]

[0099] in, The fluid mass in the pores of the target shale to be corrected under saturated conditions. k For conversion factors, specifically, k It is a constant.

[0100] In this embodiment, the fluid volume in the pores of the target shale to be corrected under saturated conditions is determined based on fluid mass and fluid density, and can be expressed by the following formula.

[0101]

[0102] in, ρ For fluid density, The fluid volume in the pores of the target shale to be corrected under saturated conditions.

[0103] In this embodiment, the porosity of the target shale to be corrected is determined based on the fluid volume and the shale volume of the target shale to be corrected, and can be expressed by the following formula.

[0104]

[0105] in, φ V represents the porosity of the target shale to be corrected, and V represents the shale volume of the target shale to be corrected.

[0106] As an example, determining the conversion coefficient between signal amplitude and fluid mass can be achieved through experimental calibration or by using known standard samples to establish a linear relationship between the NMR signal amplitude and fluid mass, thus obtaining the conversion coefficient. Substituting the third signal amplitude into the established linear relationship, the fluid mass in the pores of the target shale to be corrected under saturated conditions is calculated. Dividing the fluid mass by the fluid density yields the fluid volume. Dividing the fluid volume by the shale volume and then multiplying by 100% gives the porosity of the target shale to be corrected. This accurate porosity is then used to complete the porosity correction of the target shale.

[0107] Step S302: Based on the amplitude of the one-dimensional nuclear magnetic solid skeleton signal of the target shale to be corrected and the one-dimensional nuclear magnetic T2 spectrum of the target shale to be corrected under saturation, the pore size distribution of the target shale to be corrected is corrected.

[0108] In some embodiments, step S302 may include: performing Gaussian distribution peak fitting on the one-dimensional NMR T2 spectrum of the target shale under saturation to obtain the signal distribution of the P1 peak in the one-dimensional NMR T2 spectrum; the P1 peak characterizes the solid skeleton and partial fluid distribution of the rock; determining the one-dimensional NMR skeleton signal amplitude of the target shale under saturation based on the amplitude conversion relationship and the second signal amplitude of the target shale under saturation; replacing the amplitude in the signal distribution of the P1 peak based on the one-dimensional NMR skeleton signal amplitude to obtain the one-dimensional NMR skeleton signal distribution; subtracting the one-dimensional NMR T2 spectrum of the target shale under saturation from the one-dimensional NMR skeleton signal distribution to obtain the one-dimensional NMR T2 spectrum characterizing the pore size distribution of the target shale.

[0109] In some embodiments, Gaussian distribution peak fitting can be used to identify the signal distribution of different components in the spectrum. The P1 peak can include: a distribution representing the rock skeleton and specific pore fluid signals in a one-dimensional NMR T2 spectrum. The P1 peak can be used to characterize the rock skeleton and some fluid distributions. The one-dimensional NMR skeleton signal amplitude can include: a signal intensity value representing the rock solid skeleton in the one-dimensional NMR T2 spectrum. The one-dimensional NMR skeleton signal distribution can include: a distribution of the rock skeleton signal in the one-dimensional NMR T2 spectrum after amplitude substitution.

[0110] In this embodiment, a Gaussian distribution peak fitting is performed on the one-dimensional NMR T2 spectrum of the target shale under saturation to obtain the signal distribution of peak P1 in the one-dimensional NMR T2 spectrum. The Gaussian function expression is as follows:

[0111]

[0112] Where x is the T2 relaxation time. f ( x )for x The relaxation signal strength at time t.N This represents the number of fluid components within the shale oil reservoir. A i Let be the geometric peak area of ​​the i-th fluid component. x i Let be the transverse relaxation time of the i-th fluid component. w i Let P1 be the peak width corresponding to the standard deviation of the Gaussian distribution of the i-th fluid component. The signal distribution of the obtained P1 peak can be ( x 1. w 1. A 1).

[0113] In this embodiment, the one-dimensional NMR skeleton signal amplitude of the target shale to be corrected is determined based on the amplitude conversion relationship and the second signal amplitude of the target shale under saturation, including: calculating the one-dimensional NMR skeleton signal amplitude of the target shale to be corrected based on the following formula.

[0114]

[0115] in, This represents the geometric peak area of ​​the one-dimensional NMR skeleton signal distribution. This represents the amplitude of the third signal. 7 is the logarithmic geometric length of the one-dimensional NMR T2 distribution from 0.001ms to 10000ms (log10(10000 / 0.001)), and 200 is the number of points in the one-dimensional NMR T2 spectrum.

[0116] In this embodiment, based on the geometric peak area of ​​the one-dimensional NMR skeleton signal distribution, the peak area in the signal distribution of peak P1 is replaced to obtain the one-dimensional NMR skeleton signal distribution. Specifically, the distribution of peak P1 in the one-dimensional T2 spectrum ( x 1. w 1. A 1) Then, its peak area A 1 is replaced with the geometric peak area A of the one-dimensional NMR skeleton signal distribution. ps-1D One-dimensional NMR skeleton signal distribution can then be obtained. x 1. w 1. A ps-1D ).

[0117] As an example, Gaussian distribution peak fitting is performed on the one-dimensional NMR T2 spectrum of the target shale under saturation to obtain the signal distribution of the P1 peak in the one-dimensional NMR T2 spectrum. Through Gaussian distribution peak fitting, the complex one-dimensional NMR T2 spectrum is decomposed into multiple Gaussian peaks, identifying the signal distribution of the P1 peak representing different pore fluid components. Using the conversion relationship between the third signal amplitude and the one-dimensional / two-dimensional NMR signal amplitude of the solid skeleton signal, the one-dimensional NMR skeleton signal amplitude of the target shale is calculated. The third signal amplitude is used as the amplitude of the skeleton signal and substituted into the signal distribution of the P1 peak to obtain the distribution of the rock skeleton signal in the one-dimensional NMR T2 spectrum. Subtracting the one-dimensional NMR T2 spectrum of the target shale under saturation from the one-dimensional NMR skeleton signal distribution yields the one-dimensional NMR T2 spectrum characterizing the pore size distribution of the target shale. This completes the pore size distribution correction of the target shale.

[0118] refer to Figure 4 Application scenarios of the shale oil reservoir pore structure correction method provided in this application embodiment Figure 1 It is applied to the two-dimensional nuclear magnetic resonance T1-T2 spectra of shale in dry and saturated states.

[0119] Figure 4 In this study, based on the two-dimensional nuclear magnetic resonance T1-T2 spectrum of shale, the skeleton signal (region FG) and various fluid signals (region A: pore-bound water, region B: pore-adsorbed oil, region C: pore-bound oil, region D: mobile oil, region E: mobile water) in shale can be identified. The skeleton signal remains unchanged in both dry and saturated states.

[0120] refer to Figure 5 Application scenarios of the shale oil reservoir pore structure correction method provided in this application embodiment Figure 2 This technique is applied to the one-dimensional T2 NMR spectra of shale rocks in both dry and saturated states. (Reference) Figure 6 Application scenarios of the shale oil reservoir pore structure correction method provided in this application embodiment Figure 3 The amplitude relationship between the P1 peak in the one-dimensional NMR T2 spectrum and the skeleton signal in the two-dimensional NMR T1-T2 spectrum is applied.

[0121] like Figure 5 As shown, in the one-dimensional NMR T2 spectrum, the framework signal overlaps with the signals of region A (pore-bound water) and region B (pore-adsorbed oil), thus an intercept exists. The magnitude of the intercept term represents the fluid signals of regions A and B within the P1 peak. Therefore, as... Figure 6 As shown, in this embodiment, the correlation between the first signal amplitude and the second signal amplitude is expressed by the following formula:

[0122]

[0123] The intercept of 14.019 > 0 indicates the presence of a fluid signal in the first signal amplitude of the first shale. Therefore, the conversion relationship between the one-dimensional NMR skeleton signal amplitude and the two-dimensional NMR skeleton signal amplitude corresponding to the one-dimensional NMR T2 spectrum is as follows:

[0124]

[0125] in, The amplitude of the one-dimensional NMR skeleton signal. For the amplitude of the two-dimensional NMR skeleton signal, the goodness of fit of the correlation is given by R. 2 It means that R 2 =0.9694.

[0126] refer to Figure 7 An application scenario of the shale oil reservoir pore structure correction method provided in this application embodiment. Figure 4 It is applied to the relationship between the amplitude of a one-dimensional NMR signal and the mass of saturated oil.

[0127] like Figure 7 As shown, the amplitude and mass relationship of the one-dimensional NMR signal of oil is as follows;

[0128]

[0129] in, S fluid-1D For the amplitude of the one-dimensional nuclear magnetic resonance oil signal, m fluid-1D For oil quality, the goodness of fit of the correlation is given by R. 2 It means that R 2 =0.9767.

[0130] refer to Figure 8 An application scenario of the shale oil reservoir pore structure correction method provided in this application embodiment. Figure 5 It is applied to the relationship between one-dimensional and two-dimensional NMR porosity before and after shale correction.

[0131] Comparing the one-dimensional and two-dimensional NMR porosities before and after correction reveals that the one-dimensional NMR porosity before correction is significantly smaller than the two-dimensional NMR porosity. Furthermore, some samples with already low porosity are significantly under-corrected, indicating poor oil washing performance. The method of using a saturated state to remove the dried state during inversion results in some unwashed pore fluid being treated as substrate and removed, leading to an underestimation of the NMR porosity. In contrast, the corrected one-dimensional and two-dimensional NMR porosities show good consistency.

[0132] refer to Figure 9 An application scenario of the shale oil reservoir pore structure correction method provided in this application embodiment. Figure 6 It is applied to the pore size distribution of shale before and after correction.

[0133] The corrected one-dimensional NMR T2 spectrum was also significantly higher than the uncorrected one-dimensional NMR T2 spectrum, indicating that some fluid signals were removed before correction, and the pore size distribution characterized by the corrected one-dimensional NMR T2 spectrum was more reasonable.

[0134] The exemplary structure of the software modules included in the shale oil reservoir pore structure correction device 90 provided in this application embodiment will be further described below. In some embodiments, such as... Figure 9 As shown, the shale oil reservoir pore structure correction device 90 may include:

[0135] Test module 901 is used to perform nuclear magnetic resonance testing on the first shale in the washed oil and dried state to obtain the one-dimensional nuclear magnetic T2 spectrum and the two-dimensional nuclear magnetic T1-T2 spectrum of the first shale; T1 represents the longitudinal relaxation time and T2 represents the transverse relaxation time.

[0136] The first identification module 902 is used to identify the one-dimensional nuclear magnetic resonance T2 spectrum to obtain the first signal amplitude of the first shale;

[0137] The second identification module 903 is used to identify the two-dimensional nuclear magnetic resonance T1-T2 spectrum to obtain the second signal amplitude of the first shale;

[0138] Module 904 is established to establish the correlation between the amplitude of the first signal and the amplitude of the second signal; the correlation is used to determine the amplitude conversion relationship between the one-dimensional NMR T2 spectrum and the two-dimensional NMR T1-T2 spectrum corresponding to the skeleton signal of the first shale.

[0139] The correction module 905 is used to correct the pore structure of the target shale based on the amplitude conversion relationship and the one-dimensional NMR T2 spectrum and two-dimensional NMR T1-T2 spectrum of the target shale under saturation.

[0140] It should be noted that the description of the device in this application embodiment is similar to the description of the method embodiment above, and has similar beneficial effects as the method embodiment, therefore it will not be repeated. For any technical details not covered in the shale oil reservoir pore structure correction device provided in this application embodiment, please refer to... Figures 1 to 9 The meaning is understood in accordance with the description of any of the accompanying drawings.

[0141] According to embodiments of this application, this application also provides an electronic device and a non-transitory computer-readable storage medium.

[0142] Figure 11A schematic block diagram of an example electronic device 800 that can be used to implement embodiments of this application is shown. The electronic device is intended to represent various forms of digital computers, such as laptop computers, desktop computers, workstations, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The electronic device may also represent various forms of mobile devices, such as personal digital processors, cellular phones, smartphones, wearable devices, and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely illustrative and are not intended to limit the implementation of the application described and / or claimed herein.

[0143] like Figure 10 As shown, the electronic device 800 includes a computing unit 801, which can perform various appropriate actions and processes based on a computer program stored in a read-only memory (ROM) 802 or a computer program loaded from a storage unit 808 into a random access memory (RAM) 803. The RAM 803 may also store various programs and data required for the operation of the electronic device 800. The computing unit 801, ROM 802, and RAM 803 are interconnected via a bus 804. An input / output (I / O) interface 805 is also connected to the bus 804.

[0144] Multiple components in electronic device 800 are connected to I / O interface 805, including: input unit 806, such as keyboard, mouse, etc.; output unit 807, such as various types of displays, speakers, etc.; storage unit 808, such as disk, optical disk, etc.; and communication unit 809, such as network card, modem, wireless transceiver, etc. Communication unit 809 allows electronic device 800 to exchange information / data with other devices through computer networks such as the Internet and / or various telecommunications networks.

[0145] The computing unit 801 can be a variety of general-purpose and / or special-purpose processing components with processing and computing capabilities. Some examples of the computing unit 801 include, but are not limited to, a central processing unit (CPU), a graphics processing unit (GPU), various special-purpose artificial intelligence (AI) computing chips, various computing units running machine learning model algorithms, a digital signal processor (DSP), and any suitable processor, controller, microcontroller, etc. The computing unit 801 performs the various methods and processes described above, such as the shale oil reservoir porosity correction method. For example, in some embodiments, the shale oil reservoir porosity correction method can be implemented as a computer software program, which is tangibly contained in a machine-readable medium, such as storage unit 808. In some embodiments, part or all of the computer program can be loaded and / or installed on the electronic device 800 via ROM 802 and / or communication unit 809. When the computer program is loaded into RAM 803 and executed by the computing unit 801, one or more steps of the shale oil reservoir porosity correction method described above can be performed. Alternatively, in other embodiments, the computing unit 801 may be configured to perform a shale oil reservoir pore structure correction method by any other suitable means (e.g., by means of firmware).

[0146] Various embodiments of the systems and techniques described above herein can be implemented in digital electronic circuit systems, integrated circuit systems, field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), application-specific standard products (ASSPs), systems-on-a-chip (SoCs), payload-programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various embodiments may include implementations in one or more computer programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which may be a dedicated or general-purpose programmable processor, capable of receiving data and instructions from a storage system, at least one input device, and at least one output device, and transmitting data and instructions to the storage system, the at least one input device, and the at least one output device.

[0147] The program code used to implement the methods of this application may be written in any combination of one or more programming languages. This program code may be provided to a processor or controller of a general-purpose computer, special-purpose computer, or other programmable data processing device, such that when executed by the processor or controller, the functions / operations specified in the flowcharts and / or block diagrams are implemented. The program code may be executed entirely on a machine, partially on a machine, as a standalone software package partially on a machine and partially on a remote machine, or entirely on a remote machine or server.

[0148] In the context of this application, a machine-readable medium can be a tangible medium that may contain or store a program for use by or in conjunction with an instruction execution system, apparatus, or device. A machine-readable medium can be a machine-readable signal medium or a machine-readable storage medium. Machine-readable media can be, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, apparatus, or devices, or any suitable combination of the foregoing. More specific examples of machine-readable storage media include electrical connections based on one or more wires, portable computer disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), optical fibers, portable compact disk read-only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination of the foregoing.

[0149] To provide interaction with a user, the systems and techniques described herein can be implemented on a computer having: a display device for displaying information to the user (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor); and a keyboard and pointing device (e.g., a mouse or trackball) through which the user provides input to the computer. Other types of devices can also be used to provide interaction with the user; for example, feedback provided to the user can be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user can be received in any form (including sound input, voice input, or tactile input).

[0150] The systems and technologies described herein can be implemented in computing systems that include backend components (e.g., as a data server), or computing systems that include middleware components (e.g., an application server), or computing systems that include frontend components (e.g., a user computer with a graphical user interface or web browser through which a user can interact with implementations of the systems and technologies described herein), or any combination of such backend, middleware, or frontend components. The components of the system can be interconnected via digital data communication of any form or medium (e.g., a communication network). Examples of communication networks include local area networks (LANs), wide area networks (WANs), and the Internet.

[0151] Computer systems can include clients and servers. Clients and servers are generally located far apart and typically interact via communication networks. Client-server relationships are created by computer programs running on the respective computers and having a client-server relationship with each other. Servers can be cloud servers, servers in distributed systems, or servers incorporating blockchain technology.

[0152] It should be understood that the various forms of processes shown above can be used to rearrange, add, or delete steps. For example, the steps described in this application can be executed in parallel, sequentially, or in different orders, as long as the desired result of the technical solution disclosed in this application can be achieved, and this is not limited herein.

[0153] The above description is merely a specific embodiment of this application, but the scope of protection of this application is not limited thereto. Any variations or substitutions that can be easily conceived by those skilled in the art within the scope of the technology disclosed in this application should be included within the scope of protection of this application. Therefore, the scope of protection of this application should be determined by the scope of the claims.

Claims

1. A method of shale oil reservoir pore structure correction, characterized in that, The method comprises the following steps: performing nuclear magnetic resonance test on the first shale to obtain one-dimensional nuclear magnetic T2 spectrum and two-dimensional nuclear magnetic T1-T2 spectrum of the first shale; T1 represents longitudinal relaxation time, and T2 represents transverse relaxation time; identifying the one-dimensional nuclear magnetic T2 spectrum to obtain first signal amplitude of the first shale; identifying the two-dimensional nuclear magnetic T1-T2 spectrum to obtain second signal amplitude of the first shale; establishing a correlation between the first signal amplitude and the second signal amplitude; the correlation is used to determine amplitude conversion relationship of one-dimensional nuclear magnetic T2 spectrum and two-dimensional nuclear magnetic T1-T2 spectrum corresponding to the skeleton signal of the first shale; the correlation between the first signal amplitude and the second signal amplitude is represented by the following formula: wherein represents a second signal amplitude, represents a first signal amplitude, α is a correlation coefficient between the first signal amplitude and the second signal amplitude, β is a fluid portion signal amplitude in the first signal amplitude of the first formation. the amplitude conversion relationship of one-dimensional nuclear magnetic T2 spectrum and two-dimensional nuclear magnetic T1-T2 spectrum corresponding to the skeleton signal of the first shale is: wherein, represents the one-dimensional NMR T2 spectrum signal amplitude corresponding to the matrix signal of the first rock sample; based on the amplitude conversion relationship, one-dimensional nuclear magnetic T2 spectrum and two-dimensional nuclear magnetic T1-T2 spectrum of the target shale to be corrected in a saturated state, the pore structure of the target shale to be corrected is corrected.

2. The method of claim 1, wherein, the pore structure of the target shale to be corrected is corrected based on the amplitude conversion relationship, one-dimensional nuclear magnetic T2 spectrum and two-dimensional nuclear magnetic T1-T2 spectrum of the target shale to be corrected in a saturated state, which comprises: performing nuclear magnetic resonance test on the target shale to be corrected in a saturated state to obtain one-dimensional nuclear magnetic T2 spectrum and two-dimensional nuclear magnetic T1-T2 spectrum of the target shale to be corrected; identifying the two-dimensional nuclear magnetic T1-T2 spectrum of the target shale to be corrected to obtain second signal amplitude of the target shale to be corrected in a saturated state; identifying the one-dimensional nuclear magnetic T2 spectrum of the target shale to be corrected to obtain total signal amplitude of the target shale to be corrected; based on the amplitude conversion relationship and the second signal amplitude of the target shale to be corrected in a saturated state, one-dimensional nuclear magnetic solid skeleton signal amplitude of the target shale to be corrected in a saturated state is determined; based on the first signal amplitude and the total signal amplitude of the one-dimensional nuclear magnetic solid skeleton signal amplitude of the target shale to be corrected in a saturated state, third signal amplitude is determined; the third signal amplitude represents pore fluid signal amplitude of the target shale to be corrected; based on the third signal amplitude, the one-dimensional nuclear magnetic solid skeleton signal amplitude and the one-dimensional nuclear magnetic T2 spectrum of the target shale to be corrected, the pore structure of the target shale to be corrected is corrected.

3. The method of claim 2, wherein, the pore structure of the target shale to be corrected is corrected based on the third signal amplitude, the one-dimensional nuclear magnetic solid skeleton signal amplitude and the one-dimensional nuclear magnetic T2 spectrum of the target shale to be corrected, which comprises: based on the third signal amplitude, fluid mass and fluid density in the pores of the target shale to be corrected in a saturated state, porosity of the target shale to be corrected is corrected; based on the one-dimensional nuclear magnetic solid skeleton signal amplitude of the target shale to be corrected and the one-dimensional nuclear magnetic T2 spectrum of the target shale to be corrected in a saturated state, pore size distribution of the target shale to be corrected is corrected.

4. The method of claim 3, wherein, The porosity of the target shale to be corrected is corrected based on the third signal amplitude, the fluid mass in the pores of the target shale to be corrected in a saturated state, and the fluid density, and the method comprises the following steps: determining a conversion coefficient between the signal amplitude and the fluid mass; determining the fluid mass in the pores of the target shale to be corrected in a saturated state based on the conversion coefficient and the third signal amplitude; determining the fluid volume in the pores of the target shale to be corrected in a saturated state based on the fluid mass and the fluid density; determining the porosity of the target shale to be corrected based on the fluid volume and the shale volume of the target shale to be corrected.

5. The method of claim 3, wherein, The pore size distribution of the target shale to be corrected is corrected based on the one-dimensional nuclear magnetic solid skeleton signal amplitude of the target shale to be corrected and the one-dimensional nuclear magnetic T2 spectrum of the target shale to be corrected in a saturated state, and the method comprises the following steps: performing Gaussian distribution peak fitting on the one-dimensional nuclear magnetic T2 spectrum of the target shale to be corrected in a saturated state to obtain the signal distribution of a P1 peak in the one-dimensional nuclear magnetic T2 spectrum; the P1 peak represents the distribution of rock skeleton and part of fluid; determining the one-dimensional nuclear magnetic skeleton signal amplitude of the target shale to be corrected based on the second signal amplitude of the target shale to be corrected and the amplitude conversion relationship between the one-dimensional nuclear magnetic signal and the two-dimensional nuclear magnetic solid skeleton signal; replacing the amplitude in the signal distribution of the P1 peak based on the one-dimensional nuclear magnetic skeleton signal amplitude to obtain a one-dimensional nuclear magnetic skeleton signal distribution; subtracting the one-dimensional nuclear magnetic skeleton signal distribution from the one-dimensional nuclear magnetic T2 spectrum of the target shale to be corrected in a saturated state to obtain a one-dimensional nuclear magnetic T2 spectrum representing the pore size distribution of the target shale to be corrected.

6. The method of claim 5, wherein, The one-dimensional nuclear magnetic skeleton signal amplitude of the target shale to be corrected is determined based on the second signal amplitude of the target shale to be corrected and the amplitude conversion relationship between the one-dimensional nuclear magnetic signal and the two-dimensional nuclear magnetic solid skeleton signal, and the method comprises the following steps: calculating the one-dimensional nuclear magnetic skeleton signal amplitude of the target shale to be corrected based on the following formula: wherein, represents the peak area of the one-dimensional NMR skeleton signal distribution geometry of the target shale to be corrected, represents the amplitude of the one-dimensional NMR skeleton signal of the target shale to be corrected; 7 is the logarithmic geometry length of the one-dimensional NMR T2 distribution of 0.001 ms-10000 ms, and 200 is the number of points of the one-dimensional NMR T2 spectrum.

7. A shale oil reservoir pore structure correction device, characterized by, comprise: a test module configured to perform nuclear magnetic resonance testing on the first shale to obtain a one-dimensional nuclear magnetic T2 spectrum and a two-dimensional nuclear magnetic T1-T2 spectrum of the first shale; T1 represents a longitudinal relaxation time, and T2 represents a transverse relaxation time; a first identification module configured to identify the one-dimensional nuclear magnetic T2 spectrum to obtain a first signal amplitude of the first shale; a second identification module configured to identify the two-dimensional nuclear magnetic T1-T2 spectrum to obtain a second signal amplitude of the first shale; a establishing module configured to establish a correlation between the first signal amplitude and the second signal amplitude; the correlation is used to determine the amplitude conversion relationship between the one-dimensional nuclear magnetic T2 spectrum and the two-dimensional nuclear magnetic T1-T2 spectrum corresponding to the skeleton signal of the first shale; the correlation between the first signal amplitude and the second signal amplitude is represented by the following formula: wherein represents a second signal amplitude, represents a first signal amplitude, α is a correlation coefficient between the first signal amplitude and the second signal amplitude, β is a fluid portion signal amplitude in the first signal amplitude of the first formation. the amplitude conversion relationship between the one-dimensional nuclear magnetic T2 spectrum and the two-dimensional nuclear magnetic T1-T2 spectrum corresponding to the skeleton signal of the first shale is wherein, represents the one-dimensional NMR T2 spectrum signal amplitude corresponding to the matrix signal of the first rock sample; The correction module is configured to correct the pore structure of the target shale to be corrected based on the amplitude conversion relationship, one-dimensional nuclear magnetic T2 spectrum and two-dimensional nuclear magnetic T1-T2 spectrum of the target shale to be corrected in a saturated state.

8. An electronic device, comprising: Comprise: at least one processor; and a memory connected with the at least one processor in communication; wherein the memory stores instructions executable by the at least one processor, and the instructions are executed by the at least one processor to enable the at least one processor to perform the method of any one of claims 1-6.

9. A non-transitory computer-readable storage medium having stored thereon computer instructions, wherein, The computer instructions are used to make the computer execute the method according to any one of claims 1-6. The computer instructions are used to make the computer execute the method according to any one of claims 1-6.

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