Method, apparatus, equipment and medium for determining contribution degree of oil production in unconventional reservoirs

Abstract

An embodiment of the present application provides a method, device, equipment, and medium for determining the oil production contribution degree of unconventional reservoirs. The method includes: determining the relationship between the wet-phase fluid saturation and the capillary pressure in the reservoir formation according to multiple reference capillary pressure curves; simulating and analyzing the fracture propagation direction and seepage pressure during the reservoir volume fracturing process to determine the three-dimensional propagation law of fractures and the artificial fracture parameters; coupling the fracture three-dimensional model and the matrix property model to obtain an integrated reservoir geological engineering model; establishing a numerical simulation model according to the relationship between the wet-phase fluid saturation and the capillary pressure and the integrated reservoir geological engineering model; performing numerical simulation on the reservoir development process through the numerical simulation model to obtain the data simulation results of the reservoir formation at different development stages; determining the oil production contribution degrees of displacement and imbibition at different development stages of the reservoir formation according to the data simulation results, providing a theoretical basis and technical support for reservoir exploitation.

Description

Technical Field

[0001] The present application relates to the technical field of oil production, and particularly to a method, device, equipment and medium for determining the contribution degree of oil production in unconventional reservoirs. Background Art

[0002] For reservoir formations with extremely low permeability, it is difficult to achieve effective displacement due to the difficulty of water injection development. Therefore, at present, horizontal well large-scale volume fracturing technology is mainly used to form a large number of artificial fractures, and then combined with water injection huff and puff technology to develop low-permeability reservoirs.

[0003] After the production area is fractured, during water injection huff and puff oil production, the spontaneous imbibition effect of capillary pressure is an important mechanism in the oil production process. However, the imbibition process is not only affected by capillary pressure, but also by the displacement pressure difference, making the imbibition mechanism more complex. In addition, for fractured reservoir formations, the injected water is prone to water channeling along the fractures formed by fracturing, resulting in low utilization of the crude oil inside the matrix.

[0004] Most of the existing studies on imbibition oil production focus on the core scale, and lack a method for quantitatively determining the contribution degree of displacement and imbibition effects to the reservoir recovery factor at the macro scale by indirectly and qualitatively analyzing the movable oil law, imbibition kinetics characteristics and their influencing factors. Summary of the Invention

[0005] Embodiments of the present application provide a method, device, equipment and medium for determining the contribution degree of oil production in unconventional reservoirs, so as to solve the problem in the prior art of lacking a quantitative analysis process for the contribution degree of displacement and imbibition effects to the recovery factor during the exploitation of unconventional reservoirs.

[0006] In a first aspect, the present application provides a method for determining the contribution degree of oil production in unconventional reservoirs, including:

[0007] Obtain reference capillary pressure curves of different types of reservoir formations, and determine a relationship characterization model between the wet-phase fluid saturation and the capillary pressure in the reservoir formation according to the multiple reference capillary pressure curves;

[0008] Conduct a simulation analysis on the fracture propagation direction and seepage pressure during the reservoir volume fracturing process, determine the three-dimensional propagation law of the reservoir volume fracturing fractures, and obtain artificial fracture parameters according to the three-dimensional propagation law;

[0009] Establish a three-dimensional fracture model according to the artificial fracture parameters, and perform a coupling process on the three-dimensional fracture model and the matrix property model to obtain an integrated reservoir geological engineering model;

[0010] Establish a numerical simulation model according to the relationship characterization model and the integrated reservoir geological engineering model;

[0011] Performing numerical simulation on the reservoir development process through the numerical simulation model to obtain the data simulation results of the reservoir at different development stages;

[0012] Analyzing and processing multiple data simulation results to obtain the analysis results, and determining the oil production contribution degrees of displacement and imbibition at different development stages of the reservoir according to the analysis results.

[0013] Optionally, simulating and analyzing the fracture propagation direction and seepage pressure during the reservoir volume fracturing process to determine the three-dimensional propagation law of the reservoir volume fracturing fractures, including:

[0014] Obtaining actual fracturing data information;

[0015] Establishing a stress field-seepage coupling mathematical model for the target study area, and simulating and analyzing the fracture propagation direction and seepage pressure based on the extended finite element method to obtain the simulation analysis results;

[0016] Determining the three-dimensional propagation law of the reservoir volume fracturing fractures according to the actual fracturing data information and the simulation analysis results.

[0017] Optionally, establishing a three-dimensional fracture model according to the artificial fracture parameters, and coupling the three-dimensional fracture model with the matrix property model to obtain an integrated reservoir geological engineering model, including:

[0018] Constructing a matrix property model according to the matrix property parameters;

[0019] Generating a fracture property model based on the artificial fracture parameters and natural fracture parameters;

[0020] Coupling the fracture property model and the matrix property model to obtain an integrated reservoir geological engineering model.

[0021] Optionally, establishing a numerical simulation model according to the relationship characterization model and the integrated reservoir geological engineering model, including:

[0022] Modifying the grid properties of the fracture-controlled transformation area in the integrated reservoir geological engineering model through the local grid encryption method and in combination with the artificial fracture parameters;

[0023] Establishing a numerical simulation model according to the relationship characterization model and the integrated reservoir geological engineering model with modified grid properties.

[0024] Optionally, performing numerical simulation on the reservoir development process through the numerical simulation model to obtain the data simulation results of the reservoir at different development stages, including:

[0025] Input the basic parameters of the reservoir development process into the numerical simulation model;

[0026] Output the pressure field map and saturation field map at different development stages through the numerical simulation model;

[0027] Take the pressure field map and saturation field map as the data simulation results.

[0028] Optionally, analyze and process multiple data simulation results to obtain an analysis result, and determine the oil production contribution degrees of displacement and imbibition at different development stages in the reservoir formation, including:

[0029] Obtain the displacement pressure difference according to the pressure field map;

[0030] Divide the target research area into a displacement-dominated area, a displacement-imbibition synergistic action area, and an imbibition-dominated area according to the relative magnitudes of the displacement pressure difference and the capillary pressure;

[0031] Determine the oil production contribution degrees of displacement dominance, displacement-imbibition synergy, and imbibition dominance at different development stages in the reservoir formation.

[0032] Optionally, the method further includes:

[0033] Classify and evaluate the pore structure distribution of the reservoir formation according to the porosity and permeability of the reservoir formation to obtain an evaluation result;

[0034] Construct a displacement pressure difference-permeability chart of the reservoir formation according to the pore structure classification and evaluation result of the reservoir formation;

[0035] Determine the influence degrees of displacement dominance, displacement-imbibition synergy, and imbibition dominance on the recovery factor respectively according to the displacement pressure difference-permeability chart.

[0036] In a second aspect, the present application provides a device for determining the oil production contribution degree of an unconventional reservoir, including:

[0037] An acquisition module, configured to acquire reference capillary pressure curves of different types of reservoir formations;

[0038] A determination module, configured to determine a relationship characterization model between the wet-phase fluid saturation and the capillary pressure in the reservoir formation according to multiple reference capillary pressure curves;

[0039] A processing module, configured to perform simulation analysis on the fracture propagation direction and seepage pressure during the reservoir volume fracturing process, determine the three-dimensional propagation law of the reservoir volume fracturing fractures, and obtain artificial fracture parameters according to the three-dimensional propagation law;

[0040] Establish a three-dimensional fracture model based on the artificial fracture parameters, couple the three-dimensional fracture model with the matrix property model to obtain an integrated reservoir geological engineering model;

[0041] Establish a numerical simulation model according to the relationship characterization model and the integrated reservoir geological engineering model;

[0042] Conduct numerical simulation on the reservoir development process through the numerical simulation model to obtain the data simulation results of the reservoir at different development stages;

[0043] Analyze and process multiple data simulation results to obtain an analysis result, and determine the oil production contribution degree of displacement and imbibition at different development stages of the reservoir according to the analysis result.

[0044] Optionally, the acquisition module is further configured to acquire actual fracturing data information;

[0045] The processing module is further configured to establish a stress field-seepage coupling mathematical model for the target study area, and simulate and analyze the fracture propagation direction and seepage pressure based on the extended finite element method to obtain a simulation analysis result;

[0046] The determination module is further configured to determine the three-dimensional propagation law of the volume fracturing fractures in the reservoir according to the actual fracturing data information and the simulation analysis result.

[0047] Optionally, the processing module is further configured to construct a matrix property model according to the matrix property parameters;

[0048] Generate a fracture property model based on the artificial fracture parameters and natural fracture parameters;

[0049] Couple the fracture property model and the matrix property model to obtain an integrated reservoir geological engineering model.

[0050] Optionally, the processing module is further configured to correct the grid properties of the fracture-controlled transformation area in the integrated reservoir geological engineering model by using the local grid encryption method and combining the artificial fracture parameters;

[0051] Establish a numerical simulation model according to the relationship characterization model and the integrated reservoir geological engineering model with corrected grid properties.

[0052] Optionally, the processing module is further configured to input the basic parameters of the reservoir development process into the numerical simulation model;

[0053] Output the pressure field map and saturation field map at different development stages through the numerical simulation model;

[0054] Use the pressure field map and the saturation field map as the data simulation results.

[0055] Optionally, the processing module is further configured to obtain a displacement pressure difference according to the pressure field map;

[0056] Divide the target study area into a displacement-dominated area, a displacement-osmosis synergistic action area, and an osmosis-dominated area according to the relative magnitudes of the displacement pressure difference and the capillary pressure;

[0057] The determination module is further configured to determine the oil production contribution degrees of displacement dominance, displacement-osmosis synergistic action, and osmosis dominance at different development stages of the reservoir formation.

[0058] Optionally, the processing module is further configured to classify and evaluate the pore structure distribution of the reservoir formation according to the porosity and permeability of the reservoir formation to obtain an evaluation result;

[0059] Construct a displacement pressure difference-permeability chart of the reservoir formation according to the classification and evaluation result of the pore structure of the reservoir formation;

[0060] The determination module is further configured to determine the influence degrees of displacement dominance, displacement-osmosis synergy, and osmosis dominance on the recovery factor respectively according to the displacement pressure difference-permeability chart.

[0061] In a third aspect, the present application provides an apparatus for determining the oil production contribution degree of an unconventional reservoir, including:

[0062] A memory;

[0063] A processor;

[0064] Wherein, the memory stores computer execution instructions;

[0065] The processor executes the computer execution instructions stored in the memory to implement the method for determining the oil production contribution degree of an unconventional reservoir as described in the first aspect and various possible implementation manners of the first aspect above.

[0066] In a fourth aspect, the present application provides a computer storage medium, on which a computer program is stored, and the computer program is executed by a processor to implement the method for determining the oil production contribution degree of an unconventional reservoir as described in the first aspect and various possible implementation manners of the first aspect above.

[0067] The present application provides a method, device, equipment and medium for determining the oil production contribution degree of unconventional reservoirs. The method includes: determining the relationship between the wet-phase fluid saturation and the capillary pressure in the reservoir by using multiple reference capillary pressure curves; simulating and analyzing the fracture propagation direction and seepage pressure during the reservoir volume fracturing process to determine the three-dimensional propagation law of fractures and artificial fracture parameters; coupling the fracture three-dimensional model and the matrix property model to obtain an integrated reservoir geological engineering model; establishing a numerical simulation model based on the relationship between the wet-phase fluid saturation and the capillary pressure and the integrated reservoir geological engineering model; numerically simulating the reservoir development process through the numerical simulation model to obtain the data simulation results of the reservoir at different development stages; determining the oil production contribution degree of displacement and imbibition at different development stages of the reservoir according to the data simulation results, providing a theoretical basis and technical support for reservoir exploitation. BRIEF DESCRIPTION OF THE DRAWINGS

[0068] The accompanying drawings are incorporated herein and constitute a part of this specification, showing embodiments consistent with the present application and, together with the specification, are used to explain the principles of the present application.

[0069] Figure 1 The flowchart of a method for determining the oil production contribution degree of an unconventional reservoir provided by an embodiment of the present application Figure 1 ;

[0070] Figure 2 The flowchart of a method for determining the oil production contribution degree of an unconventional reservoir provided by an embodiment of the present application Figure 2 ;

[0071] Figure 3 The structural schematic diagram of a device for determining the oil production contribution degree of an unconventional reservoir provided by the present application;

[0072] Figure 4 The structural schematic diagram of equipment for determining the oil production contribution degree of an unconventional reservoir provided by the present application.

[0073] Through the above-mentioned accompanying drawings, the clear embodiments of the present application have been shown, and there will be more detailed descriptions hereinafter. These drawings and textual descriptions are not intended to limit the scope of the concept of the present application in any way, but to illustrate the concept of the present application to those skilled in the art by referring to specific embodiments. DETAILED DESCRIPTION OF THE EMBODIMENTS

[0074] To make the objectives, technical solutions and advantages of the present application clearer, the technical solutions in the present application will be clearly and completely described below with reference to the accompanying drawings in the present application. Obviously, the described embodiments are some, but not all, of the embodiments of the present application. All other embodiments obtained by those of ordinary skill in the art based on the embodiments in the present application without creative efforts shall fall within the protection scope of the present application.

[0075] In the description and claims of the present invention and the above-mentioned drawings, the terms "first", "second", "third", "fourth", etc. (if any) are used to distinguish similar objects, and do not necessarily describe a specific order or sequence. It should be understood that the data used in this way can be interchanged under appropriate circumstances, so that the embodiments of the present invention described here can be implemented in an order other than those illustrated or described here.

[0076] In the embodiments of the present application, words such as "exemplary" or "for example" are used to represent examples, illustrations or explanations. Any embodiment or design solution described as "exemplary" or "for example" in the present application should not be construed as being more preferred or having more advantages than other embodiments or design solutions. Rather, the use of words such as "exemplary" or "for example" is intended to present relevant concepts in a specific manner.

[0077] For unconventional reservoir formations with extremely low permeability, such as tight oil reservoirs and shale oil reservoir formations, due to the difficulty of water injection development, it is difficult to implement effective fluid displacement. Therefore, currently, it mainly relies on the horizontal well large-scale volume fracturing technology to create numerous artificial fractures, supplemented by the water injection huff and puff technology to develop such low-permeability reservoirs.

[0078] In the exploited area after fracturing treatment, when the water injection huff and puff method is used for oil production, the spontaneous imbibition driven by capillary pressure becomes a key mechanism in the oil production process. However, the imbibition process is not only affected by the single factor of capillary pressure, but the displacement pressure difference also plays an important role, which makes the imbibition mechanism more complex.

[0079] Currently, most of the research on imbibition oil recovery focuses on the core level, and indirectly and qualitatively analyzes the movable law of crude oil, the imbibition kinetics characteristics and their influencing factors. However, on the macroscopic scale, there is a lack of a method that can quantitatively evaluate the contribution degree of displacement and imbibition to the recovery rate of unconventional reservoirs.

[0080] Aiming at the above problems existing in the prior art, the present application provides a method for determining the contribution degree of oil production in unconventional reservoirs. This method is aimed at the unconventional reservoir formations after fracturing treatment, classifies and evaluates the pore structure distributions of different types of reservoirs, depicts the fracture propagation law and the zonal seepage characteristics after fracturing, establishes a geological engineering integrated model coupling the main fractures - microfractures - matrix and a numerical simulation model of the displacement - imbibition mechanism, and analyzes the contribution degree of displacement and imbibition to the recovery rate at each development stage of the reservoir formation.

[0081] The following uses specific embodiments to elaborate in detail on the technical solution of this application and how the technical solution of this application solves the above technical problems. These several specific embodiments below can be combined with each other, and the same or similar concepts or processes may not be repeated in some embodiments. The embodiments of this application will be described below in conjunction with the accompanying drawings.

[0082] Figure 1 is the flow of a method for determining the contribution degree of oil production in unconventional reservoirs provided by an embodiment of this application Figure 1 . As Figure 1 shown, the method for determining the contribution degree of oil production in unconventional reservoirs provided in this embodiment includes:

[0083] S101: Obtain the reference capillary pressure curves of different types of reservoir formations, and determine the relationship characterization model between the wet-phase fluid saturation and the capillary pressure in the reservoir formation according to multiple reference capillary pressure curves.

[0084] Among them, the capillary pressure curve is the relationship curve between the capillary pressure and the wet-phase saturation in the porous medium of the reservoir. The relationship characterization model between the wet-phase fluid saturation and the capillary pressure is used to describe the dimensionless relationship between the capillary pressure and the fluid saturation in the reservoir.

[0085] Specifically, in this embodiment, a tight / shale oil reservoir is selected as the research object. It can be understood that the permeabilities and porosities of different types of tight / shale oil reservoir formations are different. Therefore, it is necessary to select representative real cores according to the porosity and permeability boundaries of different types of tight / shale oil reservoir formations, conduct high-pressure mercury injection experiments on the selected cores, and set the maximum mercury injection pressure. The maximum mercury injection pressure can be, for example, 200 MPa. By analyzing and processing the mercury injection experiment results of different types of cores, the reference capillary pressure curves of different types of reservoir formations are determined.

[0086] It can be understood that since a certain capillary pressure corresponds to a certain pore throat radius, the capillary pressure curve actually contains the distribution law of the pore throats of the rock sample. Specifically, according to the mercury injection pressure value, the expression for calculating the pore throat radius is:

[0087]

[0088] Furthermore, according to the obtained reference capillary pressure curves of different types of reservoir formations, the relationship curve between the J function and the wet-phase fluid saturation S w is obtained, and then the J function~S w relationship characterization model of different types of reservoir formations is fitted and determined.

[0089] Among them, the J function is defined as the ratio of the measured capillary pressure to the reference capillary pressure. The conversion relationship between the J function and the reference capillary pressure is as follows:

[0090]

[0091] Among them, is the mercury-air interfacial tension, is the oil-water interfacial tension, is the gas-water interfacial tension; is the mercury injection pressure, is the oil-water capillary pressure, is the gas-water capillary pressure; is the contact angle of mercury-air, is the contact angle of oil-water, is the contact angle of gas-water; is the permeability; is the porosity.

[0092] Furthermore, by statistically analyzing pore structure characteristic parameters such as displacement pressure, pore throat radius distribution, average pore throat radius, maximum pore throat radius, and sorting coefficient, the microscopic pore structure characteristics of different types of tight / shale reservoirs can also be obtained.

[0093] By obtaining and analyzing the reference capillary pressure curves of different types of reservoir formations and establishing a relationship characterization model between wet-phase fluid saturation and capillary pressure based on these data, important reference bases can be provided for reservoir evaluation and development.

[0094] S102: Simulate and analyze the fracture propagation direction and seepage pressure during reservoir volume fracturing, determine the three-dimensional propagation law of reservoir formation volume fracturing fractures, and obtain artificial fracture parameters according to the three-dimensional propagation law.

[0095] It can be understood that according to geological data such as the geological structure, lithology, porosity, and permeability of the reservoir and data such as injection pressure and displacement during the reservoir volume fracturing construction process. Numerical methods such as finite element analysis are used to simulate the propagation behavior of fractures in different directions and depths.

[0096] Furthermore, by calculating the seepage pressure at each point during the fracture propagation process, analyzing the influence of pressure distribution on fracture propagation, and determining the fracture propagation direction under different stress fields.

[0097] Furthermore, the fracture propagation model can be optimized by adjusting control parameters, and the simulation results can be compared with on-site logging data and production data to verify the accuracy of the model.

[0098] Through the above steps, the fracture propagation and seepage pressure during reservoir volume fracturing can be systematically simulated, thereby determining the key parameters of artificial fractures and providing a scientific basis for reservoir development.

[0099] S103: establishing a three-dimensional fracture model according to the artificial fracture parameters, and coupling the three-dimensional fracture model with a matrix property model to obtain an integrated reservoir geology and engineering model.

[0100] It can be understood that in this embodiment, the fracture geometric model is established by using fracture parameters, the geological model of the reservoir is established using geological data, including porosity, permeability, saturation and net-to-gross ratio, etc., and the matrix property model is gridded to be coupled with the fracture model.

[0101] Furthermore, the fracture model and matrix model are spatially aligned and meshed consistently. By determining the interactions between fractures and the matrix, such as the effect of fractures on matrix stress and fluid conduction, the fracture model and matrix property model are integrated to establish a unified reservoir geology-engineering integrated model.

[0102] A three-dimensional fracture model is established based on the artificial fracture parameters and coupled with the matrix property model to obtain an integrated reservoir geology and engineering model. This step can more accurately understand the reservoir characteristics and engineering conditions, providing a scientific basis for reservoir exploitation.

[0103] S104: Establishing a numerical simulation model based on the relationship representation model and the reservoir geology-engineering integrated model.

[0104] It can be understood that the relationship characterization model between the wet phase fluid saturation and capillary pressure in the reservoir reflects the properties of the fluid in the reservoir, and the geological engineering integrated model comprehensively reflects the characteristics of the matrix and fractures. The numerical simulation model constructed based on the two can fully reflect the geological conditions of the reservoir.

[0105] Furthermore, in this embodiment, in order to better simulate the flow field distribution characteristics of the reservoir after fracturing, the target study area is divided into main fracture areas, fracturing-induced areas, and matrix un-induced areas.

[0106] It can be understood that the displacement effect mainly occurs in the main fracture area, and the fluid is rapidly replaced by a large driving force; the capillary imbibition effect mainly occurs in the fractured zone and the unreformed matrix area, and the fluid is sucked into small pores and fractures through capillary action.

[0107] This numerical simulation model can accurately simulate the fluid flow behavior of the reservoir after fracturing and reflects the fluid dynamic mechanism under the dual effects of displacement and capillary imbibition.

[0108] S105: numerically simulate the oil reservoir development process using the numerical simulation model to obtain data simulation results of the oil reservoir at different development stages.

[0109] It is understandable that basic parameters of the reservoir development process, including but not limited to geological structure data, fluid property parameters, etc., are input into the numerical simulation model. After receiving the above parameters, the numerical simulation model simulates the fluid dynamic changes in the reservoir at different development stages, and then determines key characteristics such as the pressure distribution changes and saturation distribution of the fluid in the reservoir.

[0110] Furthermore, pressure field maps and saturation field maps for each development stage are output according to the numerical simulation model. Among them, the pressure field map intuitively shows the pressure distribution at different positions inside the reservoir and its changing trend over time. The saturation field map depicts the spatial distribution of the fluid in the reservoir and its dynamic changes.

[0111] S106: Analyze and process the multiple data simulation results to obtain an analysis result, and determine the oil production contribution degrees of displacement and imbibition at different development stages in the reservoir according to the analysis result.

[0112] It is understandable that according to the pressure field map output by the numerical simulation model, the displacement pressure difference at different positions in the target research area can be determined. Among them, the displacement pressure difference reflects the pressure difference between the front end and the rear end of the fluid, and is the main driving force for the fluid displacement process.

[0113] Furthermore, based on the relative magnitudes of the displacement pressure difference and the capillary pressure in the reservoir, the target research area is divided into a displacement-dominated area, a displacement-imbibition synergy area, and an imbibition-dominated area.

[0114] Even further, by comparing the pressure field maps and saturation field maps at different time points, observing the fluid distribution and dynamic changes, the oil production contribution degrees of displacement and imbibition at different development stages in the reservoir are determined.

[0115] Through this process, the contributions of each area to the overall fluid dynamics and recovery effect at different development stages can be quantified, so as to formulate a more scientific and reasonable exploitation plan.

[0116] A method for determining the oil production contribution degree of unconventional reservoirs provided by an embodiment of the present application. This method determines the relationship between the wet-phase fluid saturation and the capillary pressure in the reservoir by multiple reference capillary pressure curves; simulates and analyzes the fracture propagation direction and seepage pressure during the reservoir volume fracturing process to determine the three-dimensional propagation law of fractures and artificial fracture parameters; couples the fracture three-dimensional model with the matrix property model to obtain an integrated reservoir geological engineering model; establishes a numerical simulation model based on the relationship between the wet-phase fluid saturation and the capillary pressure and the integrated reservoir geological engineering model; numerically simulates the reservoir development process through the numerical simulation model to obtain the data simulation results of the reservoir at different development stages; determines the oil production contribution degrees of displacement and imbibition at different development stages of the reservoir, providing a theoretical basis and technical support for reservoir exploitation.

[0117] Figure 2 The flow chart of a method for determining the oil production contribution degree of unconventional reservoirs provided by an embodiment of the present application Figure 2 。This embodiment is based on Figure 1 On the basis of the embodiment, a possible implementation manner of the method for determining the oil production contribution degree of unconventional reservoirs is described in detail. As Figure 2 shown, the method includes:

[0118] S201: Obtain the reference capillary pressure curves of different types of reservoir, and determine the relationship characterization model between the wet-phase fluid saturation and the capillary pressure in the reservoir according to multiple reference capillary pressure curves.

[0119] Among them, step S201 is similar to the above step S101 and will not be elaborated here.

[0120] S202: Obtain the actual fracturing data information.

[0121] Among them, the actual fracturing data information is the second-by-second data collected in real time during the actual fracturing construction process, including but not limited to key parameters such as sand addition ratio, oil pressure, casing pressure, discharge flow rate, and casing flow rate.

[0122] Obtaining the second-by-second data during the actual fracturing process is beneficial to determining the three-dimensional propagation law of volume fracturing fractures according to the above data information in the subsequent steps.

[0123] S203: Establish a stress field-seepage coupling mathematical model for the target study area, and simulate and analyze the fracture propagation direction and seepage pressure based on the extended finite element method to obtain the simulation analysis results.

[0124] Among them, the target study area is the area of actual reservoir exploitation. The stress field-seepage coupling mathematical model is used to describe the interaction relationship between fluid flow and the stress state of rock and soil mass.

[0125] Specifically, in this embodiment, based on the displacement discontinuity theory and fracture mechanics principle, a stress field-seepage coupling mathematical model for the target study area is established, and the fracture propagation direction and seepage pressure are simulated and analyzed based on the extended finite element method.

[0126] It can be understood that the displacement discontinuity theory is an effective fracture analysis method that takes into account the displacement discontinuity on the crack surface. The fracture mechanics principle provides the criteria and calculation methods for crack propagation and is an important basis for establishing the stress field-seepage coupling mathematical model. The stress field-seepage coupling mathematical model comprehensively considers the stress state, seepage characteristics of the rock and soil mass, and their interaction.

[0127] By simulating and analyzing the fracture propagation direction and seepage pressure, the simulation analysis results are obtained, which is beneficial to determining the propagation law of the volume fracturing fractures in the reservoir in the subsequent steps according to the results.

[0128] S204: Determine the three-dimensional propagation law of the volume fracturing fractures in the reservoir according to the actual fracturing data information and the simulation analysis results.

[0129] It can be understood that the crack propagation behavior under different working conditions can be simulated by adjusting the control parameters and boundary conditions of the stress field-seepage coupling mathematical model. According to the simulation results, analyze the propagation direction, propagation speed of the crack and the influence of seepage pressure on crack propagation, and combine the actual fracturing situation to determine the three-dimensional propagation law of the volume fracturing fractures in the reservoir.

[0130] It should be noted that after the model is established, the accuracy and reliability of the model should be verified by comparing with the actual data. If there are large differences between the model and the actual data, the model should be adjusted and optimized.

[0131] S205: Obtain the artificial fracture parameters according to the three-dimensional propagation law.

[0132] Among them, the artificial fracture parameters include but are not limited to parameters such as fracture half-length, fracture width, effective permeability, conductivity, skin factor, etc.

[0133] In this embodiment, based on the shut-in pressure drop data after fracturing, a finite conductivity numerical well test model for the fractured well in the reservoir reflecting the above fracture propagation law is established, and the shut-in pressure drop curve and production history curve are fitted and corrected to determine the artificial fracture parameters such as fracture half-length, fracture width, effective permeability, conductivity, skin factor, etc.

[0134] For the fractured production wells with frequent work system changes or oil-water co-production, the accuracy of the fracture parameter inversion interpretation can be improved by the method of piecewise fitting.

[0135] S206: Construct a matrix property model according to the matrix property parameters.

[0136] Matrix attributes include, but are not limited to, porosity, permeability, saturation, and net-to-gross ratio. The matrix attribute model reflects the physical properties inside the reservoir.

[0137] Specifically, in this embodiment, based on the reservoir structure model and the interpretation results of the logging data, the sequential Gaussian method is used to establish a sedimentary facies model and matrix attribute models such as porosity, permeability, saturation, and net-to-gross ratio.

[0138] S207: Generate a fracture attribute model based on the artificial fracture parameters and the natural fracture parameters.

[0139] Specifically, in this embodiment, based on rock mechanics theory and well logging data, a single-well rock mechanics parameter model and a three-dimensional geostress model of the target area are established.

[0140] A natural fracture model is generated based on fracture properties, fracture density, and cumulative density curves. Furthermore, the fracture grid properties are coarsened based on geostatistical methods to generate a fracture property model that can be used for simulation calculations, and to finely characterize the morphology and scale of natural fractures and artificial fractures of different scales.

[0141] S208: Coupling the fracture attribute model and the matrix attribute model to obtain an integrated reservoir geology and engineering model.

[0142] It is understood that the data formats of the fracture attribute model and the matrix attribute model must be unified to ensure spatial and temporal consistency, facilitating data integration. If the meshing of the fracture attribute model and the matrix attribute model is consistent, the two can be superimposed and geostatistical methods can be used to integrate the data of the fracture attribute model and the matrix attribute model to obtain an integrated reservoir geology and engineering model.

[0143] S209: Modifying the grid attributes of the fracture-controlled transformation area in the reservoir geology-engineering integrated model by using a local grid encryption method and combining the artificial fracture parameters.

[0144] It can be understood that local mesh refinement refers to the process of finer mesh division in a specific area during the meshing process. Local mesh refinement can improve the numerical simulation accuracy of a specific area while maintaining computational efficiency.

[0145] Specifically, in this embodiment, the fracture-controlled stimulation zone during oil reservoir production can be further divided into a main fracture zone and a hydraulic fracture stimulation zone. The main fracture zone includes the main hydraulic fractures and the area directly affected by them, while the hydraulic fracture stimulation zone includes the area affected by microfractures and secondary fractures.

[0146] Furthermore, for the main fracture zone, the fracturing transformation zone, and the untransformed matrix zone, a local grid refinement method is adopted. According to the artificial fracture parameters obtained in the above steps, the grid properties of the above areas are corrected, and parameters such as permeability, porosity, and fluid physical properties are assigned to each grid cell.

[0147] S210: Establish a numerical simulation model based on the relationship characterization model and the reservoir geologic-engineering integrated model with corrected grid properties.

[0148] Among them, the relationship characterization model is used to reflect the correlation between the wet-phase fluid saturation and the capillary pressure in the reservoir, and the reservoir geologic-engineering integrated model with corrected grid properties finely depicts the geological conditions at different grids.

[0149] Specifically, in this embodiment, by integrating the parameters and formulas of the relationship characterization model of the wet-phase fluid saturation and capillary pressure and the reservoir geologic-engineering integrated model with corrected grid properties, a numerical simulation model for numerical simulation is constructed. Further, the model is run using numerical simulation software to simulate the flow process of the fluid in the reservoir.

[0150] It can be understood that the numerical simulation model obtained by integrating the relationship characterization model and the geologic-engineering integrated model with corrected grid properties can more finely describe the differential seepage laws in the main fracture zone, the fracturing transformation zone, and the untransformed matrix zone. Further, it is beneficial to simulate the reservoir development process according to this numerical simulation model in the subsequent steps, and then output accurate numerical simulation results.

[0151] S211: Input the basic parameters of the reservoir development process into the numerical simulation model.

[0152] Among them, the basic parameters of the reservoir development process include: the number of grids, the grid step size, the reservoir depth, the fracture length, the injection rate, the shut-in time, etc.

[0153] By inputting the above basic parameters into the numerical simulation model, it is beneficial for the numerical simulation model to output corresponding simulation results according to the above parameters.

[0154] S212: Output the pressure field map and saturation field map at different development stages through the numerical simulation model.

[0155] In this embodiment, through the numerical simulation model obtained in the above steps, an integrated flow simulation of the injection-shut-in-flowback development process of the tight / shale oil reservoir is carried out, and then the pressure field and saturation field maps at different development stages are obtained.

[0156] Run the model in the numerical simulation software to simulate the fluid flow process at different development stages. By setting the time step and the simulation time range, determine the variation of parameters such as fluid pressure and saturation over time.

[0157] S213: Use the pressure field map and the saturation field map as the data simulation results.

[0158] It can be understood that through the above simulation process, the pressure field and saturation field maps at different development stages can be obtained. Based on the pressure field map and the saturation field map, the pressure values and saturation values of each grid cell at different time steps can be obtained.

[0159] S214: Obtain the displacement pressure difference according to the pressure field map.

[0160] It can be understood that points or lines that can reflect the pressure change during the fluid flow process are selected in the fluid flow direction, and the corresponding pressure values are read at the selected points or lines. Further, based on the read pressure values, the pressure difference in the fluid flow direction is determined. Specifically, the pressure difference obtained by subtracting the pressure value at the outflow end from the pressure value at the inflow end is the displacement pressure difference.

[0161] In practical applications, the magnitude of the displacement pressure difference is of great significance for evaluating the fluid displacement effect, optimizing the development strategy, etc.

[0162] S215: Divide the target research area into a displacement-dominated area, a displacement - imbibition synergistic action area, and an imbibition-dominated area according to the relative magnitudes of the displacement pressure difference and the capillary pressure.

[0163] In this embodiment, the underground fluid flow region is divided into a displacement-dominated area, a displacement - imbibition synergistic action area, and an imbibition-dominated area according to the relative magnitudes of the displacement pressure difference ΔP and the capillary pressure Pc.

[0164] It can be understood that in the displacement-dominated area, the displacement pressure difference ΔP is significantly greater than the capillary pressure Pc; in the displacement - imbibition synergistic action area, the displacement pressure difference ΔP is comparable to the capillary pressure Pc, and both act on the fluid flow together; in the imbibition-dominated area, the capillary pressure Pc is significantly greater than the displacement pressure difference ΔP.

[0165] Specifically, the area where ΔP > 1.2Pc is divided into the displacement-dominated area, the area where 0.8Pc < ΔP < 1.2Pc is divided into the displacement - imbibition synergistic action area, and the area where ΔP < 0.8Pc is divided into the imbibition-dominated area.

[0166] S216: Determine the oil production contribution degrees of displacement dominance, displacement - imbibition synergy, and imbibition dominance at different development stages.

[0167] It is understandable that the properties of fluids in the reservoir change over the development time, and the degrees of the effects of displacement and imbibition also change accordingly at different times.

[0168] Specifically, in the initial stage of production, the displacement effect is the main driving force for development; as the development progresses, the displacement-imbibition synergistic effect becomes dominant; in the late stage of development, due to the decline of formation energy, the imbibition effect becomes the main driving force for development.

[0169] Determining the degrees of the effects of displacement-dominated, displacement-imbibition synergistic, and imbibition-dominated at different development stages, and then continuously optimizing and adjusting the production strategy is beneficial to improving the recovery factor.

[0170] In an optional embodiment, a method for determining the oil production contribution degree of an unconventional reservoir further includes: according to the classification and evaluation results of the pore structure of the reservoir, regressing the relationship formula between the average pore throat radius and permeability, constructing a displacement pressure difference-permeability chart for different types of reservoirs considering the influence of the wetting angle and interfacial tension, and determining the influence of the three mechanical mechanisms of displacement-dominated, displacement-imbibition synergistic, and imbibition-dominated on the recovery factor at the reservoir scale.

[0171] This method can quickly and quantitatively evaluate the displacement-imbibition oil production law of tight / shale reservoirs, and provide guidance for the displacement-imbibition synergistic injection-production optimization in the whole life cycle and improving the matrix utilization degree.

[0172] A method for determining the oil production contribution degree of an unconventional reservoir provided by an embodiment of the present application includes: by obtaining actual fracturing data information, establishing a stress field-seepage coupling mathematical model for the target study area, simulating and analyzing the fracture propagation direction and seepage pressure to obtain the simulation analysis results, determining the three-dimensional propagation law of volume fracturing fractures in the reservoir according to the actual fracturing data information and the simulation analysis results, integrating the fracture attribute model and the matrix attribute model to obtain an integrated reservoir geological engineering model, modifying the grid attributes of the fracture-controlled reconstruction area in the integrated reservoir geological engineering model by the local grid encryption method and combining with artificial fracture parameters, establishing a numerical simulation model according to the relationship characterization model and the integrated reservoir geological engineering model with modified grid attributes, outputting the pressure field map and saturation field map at different development stages through the numerical simulation model, obtaining the displacement pressure difference according to the pressure field map, and dividing the target study area into a displacement-dominated area, a displacement-imbibition synergistic area, and an imbibition-dominated area according to the relative magnitudes of the displacement pressure difference and the capillary pressure, determining the oil production contribution degrees of displacement-dominated, displacement-imbibition synergistic, and imbibition-dominated at different development stages, providing a theoretical basis and technical support for the reservoir production process, and helping to improve the recovery factor of the reservoir.

[0173] Figure 3 It is a schematic structural diagram of a device for determining the oil production contribution degree of an unconventional reservoir provided by the present application. As Figure 3As shown in the figure, the unconventional reservoir oil production contribution degree determination device 300 provided in this embodiment includes:

[0174] An acquisition module 301, configured to acquire reference capillary pressure curves of reservoir formations of different types of reservoirs;

[0175] A determination module 302, configured to determine a relationship characterization model between wet-phase fluid saturation and capillary pressure in the reservoir formation according to multiple reference capillary pressure curves;

[0176] A processing module 303, configured to perform simulation analysis on the fracture propagation direction and seepage pressure during the reservoir volume fracturing process, determine the three-dimensional propagation law of the reservoir volume fracturing fractures, and obtain artificial fracture parameters according to the three-dimensional propagation law;

[0177] Establish a three-dimensional fracture model according to the artificial fracture parameters, perform coupling processing on the three-dimensional fracture model and the matrix property model to obtain a reservoir geological engineering integrated model;

[0178] Establish a numerical simulation model according to the relationship characterization model and the reservoir geological engineering integrated model;

[0179] Perform numerical simulation on the reservoir development process through the numerical simulation model to obtain data simulation results of the reservoir formation at different development stages;

[0180] Analyze and process multiple data simulation results to obtain an analysis result, and determine the oil production contribution degrees of displacement and imbibition at different development stages of the reservoir formation according to the analysis result.

[0181] Optionally, the acquisition module 301 is further configured to acquire actual fracturing data information;

[0182] The processing module 303 is further configured to establish a stress field-seepage coupling mathematical model of the target study area, and perform simulation analysis on the fracture propagation direction and seepage pressure based on the extended finite element method to obtain a simulation analysis result;

[0183] The determination module 302 is further configured to determine the three-dimensional propagation law of the reservoir volume fracturing fractures according to the actual fracturing data information and the simulation analysis result.

[0184] Optionally, the processing module 303 is further configured to construct a matrix property model according to matrix property parameters;

[0185] Generate a fracture property model based on the artificial fracture parameters and natural fracture parameters;

[0186] Perform coupling processing on the fracture property model and the matrix property model to obtain a reservoir geological engineering integrated model.

[0187] Optionally, the processing module 303 is further configured to correct the grid attributes of the fracture-controlled transformation area in the integrated reservoir geology and engineering model by using a local grid encryption method in combination with the artificial fracture parameters;

[0188] Establish a numerical simulation model based on the relationship characterization model and the integrated reservoir geology and engineering model with corrected grid attributes.

[0189] Optionally, the processing module 303 is further configured to input the basic parameters of the reservoir development process into the numerical simulation model;

[0190] Output the pressure field map and saturation field map at different development stages through the numerical simulation model;

[0191] Use the pressure field map and saturation field map as the data simulation results.

[0192] Optionally, the processing module 303 is further configured to obtain the displacement pressure difference according to the pressure field map;

[0193] Divide the target research area into a displacement-dominated area, a displacement-osmosis synergistic action area, and an osmosis-dominated area according to the relative magnitudes of the displacement pressure difference and the capillary pressure;

[0194] The determination module 302 is further configured to determine the oil production contribution degrees of displacement dominance, displacement-osmosis synergistic action, and osmosis dominance at different development stages of the reservoir formation.

[0195] Optionally, the processing module 303 is further configured to classify and evaluate the pore structure distribution of the reservoir formation according to the porosity and permeability of the reservoir formation to obtain an evaluation result;

[0196] Construct a displacement pressure difference-permeability chart of the reservoir formation according to the classification and evaluation result of the pore structure of the reservoir formation;

[0197] The determination module 302 is further configured to determine the influence degrees of displacement dominance, displacement-osmosis synergy, and osmosis dominance on the recovery factor respectively according to the displacement pressure difference-permeability chart;

[0198] An energy storage power station capacity evaluation device provided in this embodiment can execute the method provided in the above method embodiment, and its implementation principle and technical effects are similar, which will not be elaborated here in this embodiment.

[0199] Figure 4 It is a structural schematic diagram of a device for determining the oil production contribution degree of an unconventional reservoir provided by the present application. As Figure 4As shown, the device for determining the oil production contribution degree of unconventional reservoirs provided by this application, the device 400 for determining the oil production contribution degree of unconventional reservoirs includes: a receiver 401, a transmitter 402, a processor 403, and a memory 404.

[0200] The receiver 401 is configured to receive instructions and data;

[0201] The transmitter 402 is configured to send instructions and data;

[0202] The memory 404 is configured to store computer-executable instructions;

[0203] The processor 403 is configured to execute the computer-executable instructions stored in the memory 404 to implement each step performed by the method for determining the oil production contribution degree of unconventional reservoirs in the above embodiments. For specific details, reference can be made to the relevant descriptions in the embodiments of the method for determining the oil production contribution degree of unconventional reservoirs described above.

[0204] Optionally, the above memory 404 can be either independent or integrated with the processor 403.

[0205] When the memory 404 is independently provided, the electronic device further includes a bus for connecting the memory 404 and the processor 403.

[0206] This application also provides a computer storage medium, in which computer-executable instructions are stored. When the processor executes the computer-executable instructions, the method for determining the oil production contribution degree of unconventional reservoirs as performed by the above device for determining the oil production contribution degree of reservoirs is implemented.

[0207] Those of ordinary skill in the art will understand that all or some of the steps in the methods disclosed above, and the functional modules / units in systems and devices, can be implemented as software, firmware, hardware, and appropriate combinations thereof. In the hardware implementation, the division of functional modules / units mentioned above does not necessarily correspond to the division of physical components; for example, a physical component can have multiple functions, or a function or step can be executed by several physical components in cooperation. Some or all physical components can be implemented as software executed by a processor, such as a central processing unit, a digital signal processor, or a microprocessor, or as hardware, or as an integrated circuit, such as an application-specific integrated circuit. Such software can be distributed on a computer-readable medium, which can include a computer storage medium (or non-transitory medium) and a communication medium (or transitory medium). As is well known to those of ordinary skill in the art, the term computer storage medium includes volatile and non-volatile, removable and non-removable media implemented in any method or technology for storing information, such as computer-readable instructions, data structures, program modules, or other data. Computer storage media includes, but is not limited to, RAM, ROM, EEPROM, flash memory or other memory technologies, CD-ROM, digital versatile disk (DVD) or other optical disk storage, magnetic cassettes, tapes, magnetic disk storage or other magnetic storage devices, or any other medium that can be used to store the desired information and can be accessed by a computer. In addition, it is well known to those of ordinary skill in the art that a communication medium typically includes computer-readable instructions, data structures, program modules, or other data in a modulated data signal such as a carrier wave or other transmission mechanism, and can include any information delivery medium.

[0208] After considering the specification and practicing the invention disclosed herein, those skilled in the art will readily conceive of other embodiments of the present application. The present application is intended to cover any variations, uses, or adaptations of the present application, which follow the general principles of the present application and include well-known common general knowledge or conventional technical means in the technical field not disclosed in the present application. The specification and examples are only illustrative, and the true scope and spirit of the present application are pointed out by the following claims.

[0209] It should be understood that the present application is not limited to the exact structures described above and shown in the drawings, and various modifications and changes can be made without departing from its scope. The scope of the present application is only limited by the appended claims.

Claims

1. A method for determining the contribution degree of oil production in unconventional reservoirs, characterized in that The method includes: Obtaining reference capillary pressure curves of reservoir formations of different types, and determining a relationship characterization model between the wet-phase fluid saturation and the capillary pressure in the reservoir formation according to a plurality of reference capillary pressure curves; Performing simulation analysis on the fracture propagation direction and seepage pressure during reservoir volume fracturing, determining the three-dimensional propagation law of reservoir volume fracturing fractures, and obtaining artificial fracture parameters according to the three-dimensional propagation law; Establishing a three-dimensional fracture model according to the artificial fracture parameters, and performing coupling processing on the three-dimensional fracture model and the matrix property model to obtain an integrated reservoir geological engineering model; For the integrated reservoir geological engineering model, dividing the fracture-controlled transformation area in the target study area into a main fracture area and a fracturing transformation area; For the main fracture area, the fracturing transformation area, and the untransformed matrix area, adopting a local grid refinement method, and correcting the grid attributes of the main fracture area, the fracturing transformation area, and the untransformed matrix area according to the artificial fracture parameters to obtain the integrated reservoir geological engineering model with corrected grid attributes; wherein, the untransformed matrix area belongs to the area in the target study area; Integrating the parameters and formulas of the relationship characterization model and the integrated reservoir geological engineering model with corrected grid attributes to obtain a numerical simulation model; the numerical simulation model is used to simulate the flow process of fluids in the reservoir under the operation of numerical simulation software; Inputting the basic parameters of the reservoir development process into the numerical simulation model; outputting the pressure field map and saturation field map at different development stages through the numerical simulation model; taking the pressure field map and saturation field map as the data simulation results; Performing analysis and processing on a plurality of the data simulation results to obtain an analysis result, and determining the oil production contribution degrees of displacement and imbibition at different development stages in the reservoir formation according to the analysis result.

2. The method according to claim 1, wherein The performing simulation analysis on the fracture propagation direction and seepage pressure during reservoir volume fracturing, and determining the three-dimensional propagation law of reservoir volume fracturing fractures, includes: Obtaining actual fracturing data information; Establishing a stress field-seepage coupling mathematical model of the target study area, and performing simulation analysis on the fracture propagation direction and seepage pressure based on the extended finite element method to obtain a simulation analysis result; Determining the three-dimensional propagation law of reservoir volume fracturing fractures according to the actual fracturing data information and the simulation analysis result.

3. The method according to claim 1, characterized in that, The establishing a three-dimensional fracture model according to the artificial fracture parameters, and performing coupling processing on the three-dimensional fracture model and the matrix property model to obtain an integrated reservoir geological engineering model, includes: Constructing a matrix property model according to matrix property parameters; Generating a fracture property model based on the artificial fracture parameters and natural fracture parameters; Performing coupling processing on the fracture property model and the matrix property model to obtain an integrated reservoir geological engineering model.

4. The method according to claim 1, wherein The performing analysis and processing on a plurality of the data simulation results to obtain an analysis result, and determining the oil production contribution degrees of displacement and imbibition at different development stages in the reservoir formation according to the analysis result, includes: Obtaining the displacement pressure difference according to the pressure field map; According to the relative magnitudes of the displacement pressure difference and the capillary pressure, the target study area is divided into a displacement-dominated area, a displacement-osmotic imbibition synergistic action area, and an osmotic imbibition-dominated area; Determine the oil production contribution degrees of displacement dominance, displacement-osmotic imbibition synergy, and osmotic imbibition dominance at different development stages of the reservoir.

5. The method according to claim 1, wherein The method further includes: Classify and evaluate the pore structure distribution of the reservoir according to the porosity and permeability of the reservoir to obtain an evaluation result; Construct a displacement pressure difference-permeability chart of the reservoir according to the classification and evaluation result of the pore structure of the reservoir; Determine the influence degrees of displacement dominance, displacement-osmotic imbibition synergy, and osmotic imbibition dominance on the recovery factor respectively according to the displacement pressure difference-permeability chart.

6. An apparatus for determining the contribution degree of oil production in unconventional reservoirs, characterized in that, The device includes: An acquisition module for acquiring reference capillary pressure curves of different types of reservoirs; A determination module for determining a relationship characterization model between the wet-phase fluid saturation and the capillary pressure in the reservoir according to multiple reference capillary pressure curves; A processing module for simulating and analyzing the fracture propagation direction and seepage pressure during the reservoir volume fracturing process, determining the three-dimensional propagation law of the reservoir volume fracturing fractures, and obtaining artificial fracture parameters according to the three-dimensional propagation law; Establish a three-dimensional fracture model according to the artificial fracture parameters, and perform coupling processing on the three-dimensional fracture model and the matrix property model to obtain an integrated reservoir geological engineering model; For the integrated reservoir geological engineering model, divide the fracture-controlled transformation area in the target study area into a main fracture area and a fracturing transformation area; for the main fracture area, the fracturing transformation area, and the untransformed matrix area, adopt a local grid refinement method to correct the grid attributes of the main fracture area, the fracturing transformation area, and the untransformed matrix area according to the artificial fracture parameters to obtain the integrated reservoir geological engineering model with corrected grid attributes; wherein, the untransformed matrix area belongs to the area in the target study area; integrate the parameters and formulas of the relationship characterization model and the integrated reservoir geological engineering model with corrected grid attributes to obtain a numerical simulation model; the numerical simulation model is used to simulate the fluid flow process in the reservoir under the operation of numerical simulation software; Input the basic parameters of the reservoir development process into the numerical simulation model; output the pressure field map and saturation field map at different development stages through the numerical simulation model; use the pressure field map and saturation field map as the data simulation results; Analyze and process multiple data simulation results to obtain an analysis result, and determine the oil production contribution degrees of displacement and osmotic imbibition at different development stages of the reservoir according to the analysis result.

7. An equipment for determining the contribution degree of oil production in unconventional reservoirs, characterized in that, The equipment includes: A memory; A processor; Wherein, the memory stores computer execution instructions; The processor executes the computer execution instructions stored in the memory to implement an unconventional reservoir oil production contribution degree determination method as described in any one of claims 1-5.

8. A computer storage medium, characterized in that, The computer storage medium stores computer-executable instructions, which are used to implement a method for determining the contribution degree of unconventional reservoir oil production as described in any one of claims 1-5 when executed by a processor.

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