Seam control degree evaluation method based on pressure field distribution

Abstract

The invention discloses a fracture control degree evaluation method based on pressure field distribution, and the method comprises the steps: building a post-fracturing reservoir numerical model according to the reservoir geological data of a target research region and the fracturing data of a target horizontal well in the target research region; according to the post-fracturing flowback production dynamic data of the target horizontal well, pressure field change data of the target horizontal well are obtained through calculation by means of the post-fracturing oil reservoir numerical model; according to the pressure field change data around the target horizontal well, the pressure drop data of the three-dimensional layer and the fracture control area and volume of the target time point are obtained, and therefore the fracture control degree of the target horizontal well at at least one target time point is evaluated.

Description

Technical Field

[0001] The present invention belongs to the field of petroleum engineering, and relates to a method for evaluating the degree of fracture control based on the pressure field distribution. Background Art

[0002] In recent years, unconventional oil and gas reservoirs have gradually become a hot area for oil and gas development in China. To replace conventional oil and gas energy and ensure China's energy security, the exploration and development efforts have been continuously increased, and the development economic benefits have been continuously improved. As the main technology for the development of unconventional oil and gas reservoirs, multi-stage fracturing of long horizontal wells has been widely recognized and applied at home and abroad. The entire process of flowback and production after fracturing to form a complex fracture network is a complex process of multi-field coupling. Limited by on-site monitoring equipment conditions and technologies, how to characterize and evaluate the degree of fracture control remains a major problem.

[0003] Although downhole microseismic monitoring technology and wide-area electromagnetic method monitoring technology can obtain similar fracture control ranges and volumes, due to principle limitations, they can only characterize the fracture control range and volume after fracturing, and cannot characterize the fracture control range and volume after the pressure field changes during production. Although the single-well controlled reserves obtained based on the material balance method combined with production and pressure data achieve the quantification of the fracture control degree to a certain extent, they cannot be reflected in three-dimensional space, and it is difficult to describe the fracture control range. The geochemical field test analysis based on the daily liquid production chemical analysis only obtains the change of the dynamic fracture control height in the vertical direction, and it is difficult to characterize the range characteristics of the three-dimensional fracture control volume. Summary of the Invention

[0004] The purpose of the present invention is to provide a method for evaluating the degree of fracture control based on the pressure field distribution, to characterize the fracture control area and volume at the target time point, so as to solve the problem of evaluating the fracture control degree of a single well.

[0005] The purpose of the present invention is achieved by the following technical means. A method for evaluating the degree of fracture control based on the pressure field distribution includes the following steps:

[0006] Establish a numerical model of the reservoir after fracturing according to the reservoir geological data of the target research area and the fracturing data of the target horizontal well;

[0007] Fit the numerical model of the reservoir after fracturing according to the flowback production dynamic data after fracturing of the target horizontal well, and calculate the pressure field change data of the target horizontal well; the pressure field change data is used to characterize the corresponding relationship between the pressure field and the production time;

[0008] Obtain the pressure drop data, as well as the fracture control area and volume at the target time point, according to the pressure field change data of the target horizontal well and a preset pressure threshold, so as to evaluate the fracture control degree of the target horizontal well at the target time point.

[0009] The establishment of the reservoir numerical model is specifically as follows: According to the reservoir geological data, a three-dimensional geological model, a natural fracture model, and a three-dimensional geomechanics model for characterizing the reservoir characteristics of the target research area are established;

[0010] According to the fracturing data of the target horizontal well, fracturing simulation is carried out using the integrated three-dimensional geoscience model to obtain fracture parameter data for characterizing the fracture network of the target horizontal well. The integrated three-dimensional geoscience model is obtained by integrating the three-dimensional geological model, the natural fracture model, and the three-dimensional geomechanics model;

[0011] According to the fracture parameter data and the integrated three-dimensional geoscience model, a post-fracture reservoir numerical model is established through an unstructured grid division method.

[0012] The reservoir geological data includes first reservoir sub-data, second reservoir sub-data, and third reservoir sub-data. The first reservoir sub-data is used to characterize the reservoir lithofacies and physical property parameters, and a three-dimensional geological model is established through the first sub-data; the second reservoir sub-data is used to characterize the distribution and morphology of natural fractures, and a natural fracture model is established through the second reservoir sub-data; the third reservoir sub-data is used to characterize the geomechanical parameters, and an integrated three-dimensional geoscience model is established through the third reservoir sub-data, the three-dimensional geological model, and the natural fracture model.

[0013] For the integrated three-dimensional geoscience model, the vertical grid accuracy is 0.5 m, and the grid accuracy on the plane is 20 m × 20 m.

[0014] The fracture parameter data includes the distribution and morphology of artificial fractures, and the fracture conductivity.

[0015] The establishment of the post-fracture reservoir numerical model is specifically as follows: In the integrated three-dimensional geoscience model, the fracture distribution and morphology are depicted using an unstructured grid to obtain the post-fracture reservoir numerical model, and the fracture conductivity is equivalently converted into reservoir permeability.

[0016] The post-fracture flowback production dynamic data includes pressure data and production data.

[0017] The beneficial effects of the present invention are as follows: According to the reservoir geological data of the target research area and the fracturing data of the target horizontal well in the target research area, a post-fracture reservoir numerical model is established; according to the post-fracture flowback production dynamic data of the target horizontal well, the pressure field change data of the target horizontal well is calculated using the post-fracture reservoir numerical model; according to the pressure field change data around the target horizontal well, the pressure drop data in the three-dimensional layer and the fracture control area and volume at the target time point are obtained, so as to evaluate the fracture control degree of the target horizontal well at at least one target time point; it can effectively identify the fracture control characteristics at different production times, provide an effective basis for optimizing the single well cluster spacing and the platform well spacing, and can maximize the productivity of the single well and the platform. The present invention saves costs and can fully characterize the fracture control degree of the horizontal well. Brief Description of the Drawings

[0018] Figure 1 It is a schematic flow chart of a method for evaluating the degree of fracture control based on the pressure field distribution in an embodiment;

[0019] Figure 2 It is a simulation diagram of a complex fracture network;

[0020] Figure 3 It is a diagram of the degree of fracture control.

[0021] The present invention will be further described in detail below with reference to the drawings and embodiments. Detailed Embodiment

[0022] [Embodiment 1]

[0023] As Figure 1 shown, a method for evaluating the degree of fracture control based on the pressure field distribution includes the following steps:

[0024] Establish a post-fracture reservoir numerical model according to the reservoir geological data of the target research area and the fracturing data of the target horizontal well;

[0025] First, select a region as the target research area, and select one horizontal well in the target research area as the target horizontal well. Establish a post-fracture reservoir numerical model through the reservoir geological data of the target research area and the fracturing data of the target horizontal well.

[0026] The establishment of the reservoir numerical model is specifically as follows: According to the reservoir geological data, establish a three-dimensional geological model, a natural fracture model, and a three-dimensional geomechanical model for characterizing the reservoir characteristics of the target research area;

[0027] According to the fracturing data of the target horizontal well, use the integrated three-dimensional geoscience model to perform fracturing simulation to obtain fracture parameter data for characterizing the fracture network of the target horizontal well. The integrated three-dimensional geoscience model is obtained by integrating the three-dimensional geological model, the natural fracture model, and the three-dimensional geomechanical model;

[0028] According to the fracture parameter data and the integrated three-dimensional geoscience model, establish a post-fracture reservoir numerical model through the unstructured grid division method.

[0029] The post-fracture reservoir numerical model is established through the unstructured grid division method after accurately simulating the single-well fracture network according to the integrated three-dimensional geoscience model.

[0030] Specifically, based on the reservoir geological data of the target research area, a comprehensive three-dimensional geological model for characterizing the reservoir characteristics of the target research area is established; according to the fracturing data of the target horizontal well, fracturing simulation is carried out using the comprehensive three-dimensional geological model to obtain fracture parameter data for characterizing the fracture network of the target horizontal well; a post-fracture reservoir numerical model is established using the fracture parameter data and the comprehensive three-dimensional geological model.

[0031] First, based on the reservoir geological data of the target research area, including vertical well and horizontal well layer data, logging interpretation data, and seismic data, a comprehensive three-dimensional geological model is established through well-seismic fusion to characterize the reservoir characteristics of the target research area; then, using the comprehensive three-dimensional geological model and combining with the fracturing data of the target horizontal well, a fracturing model is established to simulate the complex fracture network morphology formed by fracturing, and fracture parameter data for characterizing the fracture network of the target horizontal well are obtained.

[0032] Using the fracture parameter data and the comprehensive three-dimensional geological model, a post-fracture reservoir numerical model is established; by first establishing a comprehensive three-dimensional geological model and performing fracturing simulation on this basis, a post-fracture reservoir numerical model with better simulation effects can be obtained.

[0033] The reservoir geological data includes first reservoir sub-data, second reservoir sub-data, and third reservoir sub-data. The first reservoir sub-data is used to characterize the reservoir lithofacies and physical property parameters, and a three-dimensional geological model is established through the first sub-data; the second reservoir sub-data is used to characterize the distribution and morphology of natural fractures, and a natural fracture model is established through the second reservoir sub-data; the third reservoir sub-data is used to characterize the geomechanical parameters, and a comprehensive three-dimensional geological model is established through the third reservoir sub-data, the three-dimensional geological model, and the natural fracture model.

[0034] Through the reservoir lithofacies and physical property parameters of the target research area, including porosity, permeability, and saturation, the first reservoir sub-data is obtained, and a three-dimensional geological model of the target research area is established; through the core fracture data, imaging logging data, and three-dimensional seismic fracture attribute inversion of the target research area, the distribution and morphology of natural fractures are understood, the second reservoir sub-data is obtained, and a natural fracture model of the target research area is established; through the geomechanical parameters of the target research area, including Young's modulus, Poisson's ratio, triaxial stress, etc., the third reservoir sub-data is obtained, and combined with the three-dimensional geological model and the natural fracture model, a three-dimensional geomechanical model of the target research area is established; through the combination of the first reservoir sub-data, the second reservoir sub-data, and the third reservoir sub-data, the reservoir characteristics of the target research area can be accurately and objectively characterized.

[0035] The three-dimensional geological model, the natural fracture model, and the three-dimensional geomechanical model form a comprehensive three-dimensional geological model.

[0036] Among them, secondary processing and interpretation are carried out based on the vertical well logging data within the research area. The porosity and permeability obtained from the indoor core test data are correlated and fitted with the logging data to obtain the logging porosity and permeability data.

[0037] POR = -26.7862 * ρ b +73.3613 (1)

[0038] K = 0.0065e 0.354961POR (2)

[0039] In the formula, ρ b is the rock density, g / cm 3 ; POR is the porosity, and K is the permeability, mD.

[0040] The calculation formulas of the geomechanical evaluation model for the dynamic and static Young's modulus and Poisson's ratio of the reservoir (the dynamic-static conversion formula needs to be adjusted in combination with the indoor rock mechanics experiment data) are as follows:

[0041]

[0042]

[0043]

[0044] E sta = 0.74E dyn (6)

[0045]

[0046]

[0047] v sta = 0.95v dyn (9)

[0048] In the formula, DTS is the shear wave travel time, μs / m; DTC is the compressional wave travel time, μs / m; G dyn and K dyn are the calculation coefficients of the dynamic Young's modulus; E dyn is the dynamic Young's modulus, GPa; E sta is the static Young's modulus, GPa; R sp is the calculation parameter, v dyn is the dynamic Poisson's ratio, and v sta is the static Poisson's ratio.

[0049] The calculation of the maximum and minimum horizontal principal stresses is improved on the Liuwu model by introducing the maximum and minimum horizontal principal strain coefficients. The calculation formula is as follows:

[0050]

[0051]

[0052] In the formula, σ h is the minimum horizontal principal stress, MPa; σ H is the maximum horizontal principal stress, MPa; σ v is the vertical stress, MPa; α is the effective stress coefficient, P p is the formation pore pressure, MPa; ε h is the minimum horizontal principal strain, ε H is the maximum horizontal principal strain.

[0053] Based on the understanding of core fractures, the understanding of fractures from imaging logging FMI, and the inversion of 3D seismic fracture attributes, the distribution characteristics and density characteristics of regional natural fractures are characterized. Considering natural fractures can better represent the fracture network condition after fracturing and provide a basis and input for fracture propagation simulation.

[0054] For the described comprehensive 3D geological model, the vertical grid accuracy is 0.5 m, and the grid accuracy on the plane is 20 m × 20 m.

[0055] Based on the reservoir geological data of the target study area, a structured 3D grid is designed for the study block. The vertical grid accuracy is set to 0.5 m, and equal - ratio splitting is adopted, which can accurately characterize the vertical heterogeneity. The grid accuracy on the plane is set to 20 m × 20 m, taking into account the variation characteristics of plane heterogeneity and calculation speed. Setting the vertical grid accuracy to 0.5 m and the grid accuracy on the plane to 20 m × 20 m can achieve a better balance between the model accuracy and logging accuracy and lower the computing power cost.

[0056] The described fracture parameter data includes the distribution and morphology of artificial fractures, as well as the fracture conductivity, which reflects the fracture conductivity.

[0057] The specific process of establishing the post - fracturing reservoir numerical model is as follows: In the comprehensive 3D geological model, unstructured grids are used to depict the fracture distribution and morphology to obtain the post - fracturing reservoir numerical model, and the fracture conductivity is equivalently converted into reservoir permeability.

[0058] The fracture parameter data includes data for characterizing the fracture distribution and morphology. According to the fracture data, unstructured grids are used in the comprehensive 3D geological model to depict the fracture distribution and morphology to obtain the post - fracturing reservoir numerical model. According to the fracture data, unstructured grids are used in the comprehensive 3D geological model to depict the fracture distribution and morphology because the previous plane grids were too large; at this time, the grids in the fracture area can be adjusted smaller through the unstructured grid division method, and the obtained post - fracturing reservoir numerical model is more refined.

[0059] According to the post - fracturing flow - back production dynamic data of the target horizontal well, fit the post - fracturing reservoir numerical model, and calculate the pressure field change data of the target horizontal well; the pressure field change data is used to characterize the corresponding relationship between the pressure field and the production time.

[0060] The post - fracturing flow - back production dynamic data includes pressure data and production data.

[0061] By collecting and collating the actual post - fracturing flow - back production dynamic data of the target horizontal well, including pressure data, production data, etc., and combining with the post - fracturing reservoir numerical model, the pressure field change data of the target horizontal well is calculated, which can reflect the corresponding relationship between the pressure field and the production time.

[0062] According to the pressure field change data of the target horizontal well and the preset pressure threshold, obtain the pressure drop data, as well as the fracture - controlled area and volume at the target time point, so as to evaluate the fracture - controlled degree of the target horizontal well at the target time point.

[0063] Through the pressure field change data of the target horizontal well, the pressure drop data of the pressure field of the target horizontal well can be obtained, which can reflect the pressure drop situation at each target time point compared with the start time point of post - fracturing flow - back production; according to the pressure drop data of the pressure field of the target horizontal well, the fracture - controlled degree of the target horizontal well at all target time points can be objectively and comprehensively compared and evaluated.

[0064] According to the pressure drop data of the target horizontal well, the fracture - controlled degree of the target horizontal well at all target time points can be compared and evaluated.

[0065] Then, according to the pressure drop data of the pressure field of the target horizontal well, determine the fracture - controlled area and volume of the target horizontal well at each target time point; according to the fracture - controlled area and volume of the target horizontal well at each target time point, the fracture - controlled degree of the target horizontal well at all target time points can be compared and evaluated.

[0066] Therefore, according to the pressure drop data of the pressure field of the target horizontal well, the fracture - controlled area and volume of the target horizontal well at each target time point can be obtained, which can directly compare and evaluate the fracture - controlled degree of the target horizontal well at all target time points, and more intuitively and simply characterize the fracture - controlled degree at each target time point, which is convenient for comparison.

[0067] Furthermore, by setting a preset pressure threshold and combining with the pressure drop data of the pressure field of the target horizontal well, taking the pressure drop change of the pressure field after production being greater than 50% of the original reservoir pressure as the pressure threshold for the fracture - controlled degree, the fracture - controlled area and volume of the target horizontal well at each target time point can be determined, characterizing the fracture - controlled degree of a single well in different production stages.

[0068]

Example 2

[0069] Based on Example 1, the integrated numerical model of the geological and engineering integrated Petrel platform was used for simulation.

[0070] Establish a three-dimensional comprehensive geological model, which includes three parts: three-dimensional geological modeling, natural fracture modeling and three-dimensional geomechanical modeling, and finally form an integrated comprehensive model. Three-dimensional geological modeling technology focuses on describing the three-dimensional spatial changes of reservoir parameters outside the well control range through mathematical methods such as geostatistics. Through geostatistics, multidisciplinary data can be integrated in the three-dimensional modeling process and become an important bridge for multidisciplinary team collaboration. Natural fracture modeling is based on core fracture characteristics, logging imaging fracture interpretation and seismic multi-attribute extraction to characterize multi-scale natural fractures and finely characterize the distribution and morphology of natural fractures. Three-dimensional geomechanical modeling technology is based on the understanding of geological models on formations, structures, lithology and other factors, and integrates logging, core, imaging and seismic data to characterize three-dimensional engineering quality parameters, including heterogeneous geostress fields, compressibility, rock strength, etc.

[0071] The target area for modeling is set as a rectangular area of ​​5600m×7500m. Since conventional logging data from multiple wells are required for modeling, the vertical grid is designed to be 0.5m on average and split in equal proportion. The vertical accuracy is mainly considered in the following two points: the sampling accuracy of the current mainstream logging equipment is about 0.125m; but there is a certain measurement error, and the average can more accurately reflect the formation characteristics to a certain extent. Too high vertical accuracy will lead to excessive computing power in the fracture extension simulation stage and the reservoir numerical simulation stage, and the calculation speed is slow.

[0072] Combined with the small layer comparison of regional vertical well logging data, the structural stratigraphic framework of the target area is established, and the structural stratigraphic framework model of the area is established by the inter-well interpolation method. The three-dimensional sedimentary phase and attribute modeling adopts a random modeling algorithm (Gaussian random function simulation). In the process of random modeling, it is necessary to apply geological trends (seismic inversion) as much as possible. For example, vertical trends and lateral trends are used for control in sedimentary phase modeling. Based on the vertical well logging data within the study area, secondary processing and interpretation are carried out, and the porosity and permeability obtained from the indoor core test data are correlated with the logging data to obtain the logging porosity and permeability data.

[0073] POR=-26.7862*ρ b +73.3613 (1)

[0074] K=0.0065e 0.354961POR (2)

[0075] In the formula, ρ b is the rock density, g / cm 3 ; POR is porosity, K is permeability, mD.

[0076] The calculation formulas of the geomechanical evaluation model for the dynamic and static Young's modulus and Poisson's ratio of the reservoir (the dynamic-static conversion formula needs to be adjusted in combination with indoor rock mechanics experiment data) are as follows:

[0077]

[0078]

[0079]

[0080] E sta =0.74E dyn (6)

[0081]

[0082]

[0083] v sta =0.95v dyn (9)

[0084] In the formula, DTS is the shear wave travel time difference, μs / m; DTC is the compressional wave travel time difference, μs / m; G dyn and K dyn are the calculation coefficients of the dynamic Young's modulus; E dyn is the dynamic Young's modulus, GPa; E sta is the static Young's modulus, GPa; R sp is the calculation parameter, v dyn is the dynamic Poisson's ratio, v sta is the static Poisson's ratio. The calculation of the maximum and minimum horizontal principal stresses is improved on the Liuwu model by introducing the maximum and minimum horizontal principal strain coefficients. The calculation formula is as follows:

[0085]

[0086]

[0087] In the formula, σ h is the minimum horizontal principal stress, MPa; σ H is the maximum horizontal principal stress, MPa; σ v is the vertical stress, MPa; α is the effective stress coefficient, P p is the formation pore pressure, MPa; ε h is the minimum horizontal principal strain, ε H is the maximum horizontal principal strain.

[0088] Conduct post-fracture hydraulic fracture simulation. Taking the research well as an example, collect the corresponding fracturing construction data, including the depth data of single-well segmented and clustered, proppant parameters, fracturing fluid parameters, and the pump injection second-point data of each section during actual construction. Taking the txt data format as an example, the second-point pump injection data required by the software includes the data attribute name (English characters) and the actual data value. After converting the on-site recorded excel second-point data into txt data according to the requirements, import it into the software. When conducting post-fracture fracture simulation, it is necessary to be based on the actual pump injection data, mainly including defining the fracturing fluid type, proppant type, single-step fluid volume, and sand ratio. The software can divide the second-point data into different fracturing steps according to the actual pump injection data and automatically generate the pump injection program. At the same time, for the automatic selection of the fluid type and proppant type for each step, it is necessary to give the total fluid volume of each fluid type and the total usage of each proppant, so as to improve the accuracy of the pump injection program. Generate the interface of the pump injection program and the generated pump injection program. The software can divide the second-point data into different fracturing steps according to the actual pump injection data and automatically generate the pump injection program. At the same time, for the automatic selection of the fluid type and proppant type for each step, it is necessary to give the total fluid volume of each fluid type and the total usage of each proppant, so as to improve the accuracy of the pump injection program. Generate the interface of the pump injection program and the generated pump injection program. According to the established fracturing model and the actual pump injection program, use the UFM unconventional fracture model in the software to simulate the propagation of single-stage multi-fractures. This model has unique advantages in considering the interaction between hydraulic fractures and natural fractures and the stress shadow between fractures. Based on the integrated evaluation process, during the simulation, it is necessary to correct the fracturing model according to the simulated construction pressure and fracture geometry with the actual construction pressure and microseismic monitoring data, including parameters such as in-situ stress distribution, fluid filtration performance, and string friction, and finally make the simulated construction pressure tend to be consistent with the actual construction pressure, and the fracture geometry be consistent with the distribution of microseismic event points, such as Figure 2 shown, to obtain the complex fracture network model and fracture parameter data.

[0089] According to the obtained comprehensive three-dimensional geological model and complex fracture network model, couple and establish an unstructured reservoir numerical model. Through the unstructured grid coarsening method, finely depict the complex fracture network morphology, appropriately equivalently magnify the matrix grid, and equivalent the fracture conductivity to the reservoir permeability attribute to characterize the high conductivity of the fractures.

[0090] Collect and sort out the post-fracture flowback production dynamic data of the research well, including pressure data and production data. Then conduct dynamic history matching calibration according to the post-fracture reservoir numerical model to obtain the pressure field change data of the target horizontal well.

[0091] According to the pressure field change data of the reservoir numerical model after fitting, taking the pressure drop change of the pressure field attribute after production being greater than 50% of the original reservoir pressure as the pressure threshold for the fracture control degree, obtain the pressure drop data at the target time point, such asFigure 3 The shown seam control degree diagram represents the seam control area and volume at the target time point in three-dimensional space. The seam control area and volume within the horizontal wellbore perimeter reflect the seam control degree, thus providing a clear indication of the seam control degree at the target time point of the well to be studied, facilitating the quantification and evaluation of the seam control degree.

Claims

1. A method for evaluating the fracture control degree based on pressure field distribution, characterized in that, it includes the following steps: Establish a post-fracture reservoir numerical model according to the reservoir geological data of the target research area and the fracturing data of the target horizontal well; According to the post-fracture flowback production dynamic data of the target horizontal well, fit the post-fracture reservoir numerical model and calculate the pressure field change data of the target horizontal well; the pressure field change data is used to characterize the corresponding relationship between the pressure field and the production time; According to the pressure field change data of the target horizontal well and the preset pressure threshold, obtain the pressure drop data and the fracture control area and volume at the target time point, so as to evaluate the fracture control degree of the target horizontal well at the target time point.

2. The method for evaluating the fracture control degree based on pressure field distribution according to claim 1 or 2, characterized in that: The establishment of the reservoir numerical model is specifically: according to the reservoir geological data, establish a three-dimensional geological model, a natural fracture model and a three-dimensional geomechanical model for characterizing the reservoir characteristics of the target research area; According to the fracturing data of the target horizontal well, use the integrated three-dimensional geoscience model to conduct fracturing simulation to obtain the fracture parameter data for characterizing the fracture network of the target horizontal well. The integrated three-dimensional geoscience model is obtained by integrating the three-dimensional geological model, the natural fracture model and the three-dimensional geomechanical model; According to the fracture parameter data and the integrated three-dimensional geoscience model, establish a post-fracture reservoir numerical model through the unstructured grid division method.

3. The method for evaluating the fracture control degree based on pressure field distribution according to claim 1, characterized in that: The reservoir geological data includes the first reservoir sub-data, the second reservoir sub-data and the third reservoir sub-data. The first reservoir sub-data is used to characterize the reservoir lithofacies and physical property parameters, and a three-dimensional geological model is established through the first sub-data; the second reservoir sub-data is used to characterize the distribution and morphology of natural fractures, and a natural fracture model is established through the second reservoir sub-data; the third reservoir sub-data is used to characterize the geomechanical parameters, and an integrated three-dimensional geoscience model is established through the third reservoir sub-data, the three-dimensional geological model and the natural fracture model.

4. The method for evaluating the fracture control degree based on pressure field distribution according to claim 2, characterized in that: For the integrated three-dimensional geoscience model, the vertical grid accuracy is 0.5m, and the grid accuracy on the plane is 20m×20m.

5. The method for evaluating the fracture control degree based on pressure field distribution according to claim 2, characterized in that: The fracture parameter data includes the distribution and morphology of artificial fractures and the fracture conductivity.

6. The method for evaluating the fracture control degree based on pressure field distribution according to claim 4, characterized in that: The establishment of the post-fracture reservoir numerical model is specifically: use unstructured grids in the integrated three-dimensional geoscience model to depict the fracture distribution and morphology to obtain the post-fracture reservoir numerical model, and equivalently convert the fracture conductivity into reservoir permeability.

7. The method for evaluating the fracture control degree based on pressure field distribution according to claim 1, characterized in that: The post-fracture flowback production dynamic data includes pressure data and production data.

Images