Method and device for evaluating three-dimensional comprehensive compressibility of compact sandstone reservoir horizontal well

Abstract

The invention provides a tight sandstone reservoir horizontal well three-dimensional comprehensive compressibility evaluation method and device, and belongs to the technical field of oil-gas exploration. The method comprises the following steps: performing three-dimensional modeling on geological attributes around a target horizontal well, wherein the geological attributes comprise lithology, natural fractures and oil-gas possibility; carrying out geological attribute assignment; fracturing crack propagation simulation is conducted on the penetrating interval of the target horizontal well trajectory; according to different fracture height sweep degrees of fractured fractures, establishing a mapping coefficient, and according to the mapping coefficient, mapping a geological attribute assignment result to the horizontal well to obtain a geological sweet spot index around the horizontal well; and obtaining a comprehensive compressibility evaluation result according to the evaluation parameters including the geological sweet spot indexes around the well. According to the method, lithology, natural fractures and oil-gas possibility in geological dessert attributes around a well are comprehensively considered and mapped into geological dessert indexes around the well, and then the geological dessert indexes around the well are combined with other geological, engineering and technological parameters, so that compressibility evaluation of the compact sandstone reservoir is realized.

Description

TECHNICAL FIELD

[0001] The application belongs to the technical field of oil and gas exploration, and particularly relates to a method for evaluating the three-dimensional comprehensive compressibility of a horizontal well in a tight sandstone reservoir, a device for evaluating the three-dimensional comprehensive compressibility of a horizontal well in a tight sandstone reservoir, a computer device, and a machine-readable storage medium. BACKGROUND

[0002] With the increasing number of horizontal wells year by year, multi-stage fracturing of horizontal wells has become a main technology for unconventional oil and gas exploration and development. Carrying out compressibility evaluation and optimizing horizontal well fracturing layers are important measures to improve the utilization rate of unconventional reservoirs and the post-fracturing productivity of horizontal wells.

[0003] Brittleness reflects the complexity of fractures formed after fracturing of a reservoir, and is an important parameter for quantitatively characterizing the compressibility of a shale reservoir. The brittleness evaluation method based on the content of brittle minerals in rocks and rock mechanics parameters is the earliest compressibility evaluation method. In 2007, Jarvie et al. proposed that the mass ratio of quartz minerals in a core to all minerals is an index for evaluating the brittleness of rocks. In 2008, Rickman proposed a brittleness index for characterizing the compressibility of shale reservoirs in the Fortworth basin in North America based on the Young's modulus and Poisson's ratio in rock mechanics parameters of the Barnett shale reservoir in the basin. This method is mainly aimed at shale reservoirs and the difficulty of forming a fracture network. However, this method is not suitable for low-permeability tight sandstone reservoirs under strong tectonic extrusion stress, and mainly has two problems: 1) The porosity of deep tight sandstone reservoirs is 3%-5%, and the rock components are mainly quartz and feldspar, with a quartz content of more than 80%. The content of brittle minerals and the brittleness index of different types of reservoirs have little difference, and it is difficult to distinguish them; 2) Deep tight sandstone is affected by continuous extrusion tectonic stress in a certain direction, resulting in a difference coefficient of horizontal stress of 0.3-0.5, and it is difficult to form a complex fracture network, and the overall compressibility is poor.

[0004] In 2010, Baihly and Cipolla et al. proposed that the fracturing section selection should comprehensively consider the geological engineering double dessert, that is, the reservoir quality and the completion quality should be comprehensively considered, the reservoir quality includes the lithology, the porosity, the permeability, the oil and gas bearing property parameters, and the completion quality includes the stress, the brittleness, the natural fracture, the cementing quality and the like parameters, the sensitive factors are screened by using the multi-factor analysis method, and the comprehensive fracturability index is obtained by weighted calculation. The above parameters are evaluated by using the single well logging curve, and only the reservoir geological and engineering parameters in the near wellbore range can be reflected. The low permeability and dense sandstone reservoir has strong heterogeneity, the high quality sandstone thickness and physical property change fast in the horizontal direction, and the layer is easily drilled in the horizontal well drilling process. The fracturability evaluation method proposed by the previous person is mainly based on the single well logging curve evaluation, and the possibility that the high quality reservoir near the well trajectory is connected by the fracturing fracture is not considered. The drilling display of the horizontal section is often regarded as the invalid section and is missed in the fracturing section process of the horizontal well, and the utilization efficiency of the horizontal section is reduced. The drilling display is good, but the physical property of the well wall is poor or the water layer exists, and the overall productivity is reduced after fracturing. SUMMARY

[0005] The purpose of the embodiments of the present application is to provide a tight sandstone reservoir horizontal well three-dimensional comprehensive fracturability evaluation method, a tight sandstone reservoir horizontal well three-dimensional comprehensive fracturability evaluation device, a computer equipment and a machine readable storage medium, to overcome the technical problem that the method applied to the fracturability evaluation of the shale reservoir cannot be applied to the fracturability evaluation of the tight sandstone reservoir horizontal well, and to overcome the technical problem that the fracturability evaluation method based on the geological engineering double dessert has poor accuracy when applied to the fracturability evaluation of the tight sandstone reservoir horizontal well.

[0006] In order to achieve the above purpose, the first aspect of the embodiments of the present application provides a tight sandstone reservoir horizontal well three-dimensional comprehensive fracturability evaluation method, which comprises:

[0007] Perform three-dimensional modeling of the geological properties of the well wall of the target horizontal well to obtain a well wall geological model, wherein the geological properties include lithology, natural fractures and oil and gas bearing properties;

[0008] Perform geological property assignment to distinguish the influence degree of different classifications of each geological property on the post-fracturing productivity;

[0009] Perform fracturing fracture propagation simulation on the passing layer section of the target horizontal well trajectory;

[0010] According to the different fracture height sweep degrees of the fracturing fractures, a mapping coefficient is established, and the geological property assignment result is mapped to the horizontal well trajectory according to the mapping coefficient to obtain a well wall geological dessert index;

[0011] According to the main control parameter and weight in the evaluation parameter including the well circumference geological dessert index, the comprehensive compressibility evaluation result is obtained.

[0012] Further improvement, the target horizontal well well circumference geological attribute three-dimensional modeling is carried out, and the well circumference geological model is obtained, and the geological attribute includes lithology, natural fracture and oil and gas bearing property, and the geological attribute includes:

[0013] According to the P-S wave velocity ratio, the lithology around the target horizontal well is identified;

[0014] According to the maximum likelihood attribute, the structural entropy attribute and the curvature attribute, the natural fracture is identified;

[0015] According to AVO attribute or Poisson impedance, the oil and gas bearing property is identified.

[0016] Further improvement, the geological attribute assignment is carried out, so as to distinguish the influence degree of different classification of each geological attribute on post-fracturing productivity, including:

[0017] According to the contribution degree of different lithology to post-fracturing productivity from low to high, different lithology is given from low to high score, and the type of lithology includes high-quality sandstone, poor sandstone and mudstone;

[0018] According to the contribution degree of different development degree of natural fracture to post-fracturing productivity from low to high, different natural fracture is given from low to high score, and the type of natural fracture includes development type natural fracture, relatively development type natural fracture and non-development type natural fracture;

[0019] According to the contribution degree of different oil and gas bearing property to post-fracturing productivity from low to high, different oil and gas bearing property is given from low to high score, and different oil and gas bearing property includes single phase layer, dry layer and two phase layer, single phase layer is gas layer or oil layer, and two phase layer is gas-water layer or oil-water layer.

[0020] Further improvement, the fracturing fracture propagation simulation is carried out on the passing layer section of the target horizontal well trajectory, including:

[0021] The formation longitudinal stress model of the region where the target horizontal well is located is established;

[0022] Different passing layer sections are determined according to the lithology passed by the target horizontal well trajectory;

[0023] The longitudinal stress profile corresponding to the passing layer section is obtained by using the formation longitudinal stress model;

[0024] The fracturing fracture propagation simulation is carried out based on the longitudinal stress profile.

[0025] Further improvement, the formation longitudinal stress model of the region where the target horizontal well is located is established, including:

[0026] Determine the conversion relationship between the dynamic rock mechanics parameters and the static rock mechanics parameters of the rock according to the actual logging data and the experimental data under high confining pressure in the laboratory;

[0027] Calculate the dynamic rock mechanics parameters of the rock with different lithology according to the logging data of the area where the target well is located, and calculate the static rock mechanics parameters by using the conversion relationship;

[0028] Calculate the geostress field of the area where the target horizontal well is located based on the P-wave velocity field and the S-wave velocity field and the density field obtained by geophysical inversion;

[0029] Calculate the single-well geostress of the target horizontal well according to the acoustic logging data by using the geostress calculation model;

[0030] Constrain the single-well geostress to correct the geostress field of the area where the target horizontal well is located, and obtain the formation longitudinal stress model.

[0031] Further improvement, according to the different fracture height sweep degrees of the fractured cracks, a mapping coefficient is established, and the geological attribute assignment result is mapped to the layer where the horizontal well trajectory is located according to the mapping coefficient, to obtain a two-dimensional plane attribute;

[0032] According to the different fracture height sweep degrees of the fractured cracks, a mapping coefficient is established, and the geological attribute assignment result is mapped to the layer where the horizontal well trajectory is located according to the mapping coefficient, to obtain a two-dimensional plane attribute;

[0033] Superimpose the two-dimensional plane attribute to the one-dimensional wellbore of the horizontal well trajectory to obtain the distribution of the wellbore geological sweet spot index along the horizontal well.

[0034] Further improvement, according to the different fracture height sweep degrees of the fractured cracks, a mapping coefficient is established, and the geological attribute assignment result is mapped to the layer where the horizontal well trajectory is located according to the mapping coefficient, to obtain a two-dimensional plane attribute, including:

[0035] If the vertical distance of a point in the wellbore geological model from the layer where the horizontal well trajectory is located is greater than the fracture simulation half-fracture height at the projection point of the point on the layer where the horizontal well trajectory is located, it is determined that the mapping coefficient of the point is a first output value, and the first output value is an output value obtained by inputting the difference between the vertical distance and the fracture simulation half-fracture height into an exponential decay function;

[0036] If the vertical distance of a point in the wellbore geological model from the layer where the horizontal well trajectory is located is less than or equal to the fracture simulation half-fracture height at the projection point of the point on the layer where the horizontal well trajectory is located, it is determined that the mapping coefficient of the point is a first preset value, and the first preset value is not less than 1;

[0037] For a certain geological attribute, the mapping coefficient is used to weight the assignment results of each point in the wellbore geological model under the geological attribute, and the weighted results of each point corresponding to the same projection point on the layer surface where the horizontal well trajectory is located are accumulated to obtain the superimposed assignment.

[0038] Similarly, the superimposed assignment corresponding to each geological attribute is obtained, so as to complete the mapping of the geological attribute assignment results on the layer surface where the horizontal well trajectory is located, and a two-dimensional plane attribute is obtained.

[0039] Further improvement, the two-dimensional plane attribute is superimposed and assigned to the one-dimensional wellbore of the horizontal well trajectory to obtain the wellbore geological sweet spot index distribution along the horizontal well, comprising:

[0040] For a certain geological attribute, the superimposed assignments of each point corresponding to the same projection point on the one-dimensional wellbore are accumulated to obtain a first accumulated value, and similarly, the first accumulated value of each geological attribute itself at the projection point is obtained. The first accumulated values of each geological attribute itself at the projection point are summed to obtain the wellbore geological sweet spot index of the one-dimensional wellbore at the projection point position.

[0041] Similarly, the wellbore geological sweet spot index distribution along the horizontal well is obtained.

[0042] Further improvement, the evaluation parameters include geological parameters, engineering parameters and process parameters including wellbore geological sweet spot index.

[0043] Further improvement, the comprehensive compressibility evaluation result is obtained according to the main control parameter and the weight in the evaluation parameters including the wellbore geological sweet spot index, comprising:

[0044] According to the logging data and the fracturing operation data, the geological parameters, engineering parameters and process parameters except the wellbore geological sweet spot index are obtained.

[0045] Taking the maximum production as the objective function, the influence degree of the geological parameters, engineering parameters and process parameters on the production capacity after fracturing is analyzed by using the multi-factor analysis method, and the main control parameter and the corresponding weight are determined.

[0046] According to the main control parameter and the corresponding weight, the comprehensive compressibility evaluation result is obtained.

[0047] Further improvement, the geological parameters except the wellbore geological sweet spot index include one of total hydrocarbon, drilling fluid leakage rate and fracture development index distributed along the wellbore, one of porosity, AC acoustic time difference logging value and GR measurement value.

[0048] Further improvement, the engineering parameters include brittleness index, horizontal minimum principal stress and horizontal principal stress difference coefficient.

[0049] Further improved, the process parameters include single-stage sand volume, liquid volume, displacement volume, reformation volume and fracture complexity.

[0050] The second aspect of the embodiment of the present application provides a device for evaluating three-dimensional comprehensive compressibility of a horizontal well in a tight sandstone reservoir, and the device comprises:

[0051] A wellbore geological model construction module is configured to perform three-dimensional modeling of geological properties around a target horizontal well, and obtain a wellbore geological model, wherein the geological properties include lithology, natural fractures and oil and gas bearing property.

[0052] A geological property assignment module is configured to assign geological properties to distinguish the influence degree of different classifications of the geological properties on post-frac productivity.

[0053] A fracturing fracture propagation simulation module is configured to simulate fracturing fracture propagation in a layer segment through which a trajectory of the target horizontal well passes.

[0054] A wellbore geological sweet spot index mapping module is configured to establish a mapping coefficient according to different fracture height sweep degrees of the fracturing fractures, and map the geological property assignment result to the horizontal well trajectory according to the mapping coefficient to obtain a wellbore geological sweet spot index.

[0055] A comprehensive compressibility evaluation module is configured to obtain a comprehensive compressibility evaluation result according to main control parameters and weights in evaluation parameters including the wellbore geological sweet spot index.

[0056] The third aspect of the embodiment of the present application provides a computer device, which comprises a memory, a processor and a computer program stored in the memory and executable on the processor, and the processor implements the method for evaluating three-dimensional comprehensive compressibility of a horizontal well in a tight sandstone reservoir according to the first aspect of the embodiment of the present application when executing the program.

[0057] The fourth aspect of the embodiment of the present application provides a machine readable storage medium, which stores a computer program, and the computer program is executable on a processor to implement the method for evaluating three-dimensional comprehensive compressibility of a horizontal well in a tight sandstone reservoir according to the first aspect of the embodiment of the present application.

[0058] The low-permeability tight sandstone reservoir has strong heterogeneity, and the thickness and physical property of high-quality sandstone change fast in the horizontal direction, so the horizontal well is prone to enter a sandstone box adjacent to high-quality sandstone or containing a mudstone interlayer during drilling, and the vertical coverage degree of the horizontal well is limited due to the shielding of the mudstone interlayer. Based on the above characteristics of the tight sandstone reservoir, if the geological engineering double sweet spot comprehensive compressibility evaluation method for a shale reservoir in the prior art is directly applied to the low-permeability tight sandstone reservoir, many problems will inevitably be encountered, thereby leading to low post-frac productivity.

[0059] In the technical solution, the three geological properties of the lithology, natural fractures and oil and gas bearing property around the horizontal well are considered, and the mapping coefficient is set according to the swept degree of the fracture height of the fracturing fracture, that is, the farther the distance from the horizontal well track in the vertical direction, the smaller the influence of the geological properties of each point in the geological model around the well on the fracturing of the horizontal well, and vice versa, and then the mapping result of the geological property assignment is mapped to the horizontal well track, and the mapping result is taken as the consideration value of the geological sweet spot property around the well, that is, the geological sweet spot index defined in the technical solution, and after the geological sweet spot index is determined, it is added to the comprehensive compressibility evaluation parameter, so that the evaluation accuracy is improved, the selection of low-efficiency layers or the omission of potential layers during fracturing is avoided, and the post-fracturing productivity is improved.

[0060] Other features and advantages of the embodiments of the present application will be described in detail in the following specific embodiments. BRIEF DESCRIPTION OF DRAWINGS

[0061] The accompanying drawings are included to provide a further understanding of the embodiments of the present application, and constitute a part of the specification, and are used together with the following specific embodiments to explain the embodiments of the present application, but do not constitute a limitation on the embodiments of the present application. In the drawings:

[0062] Figure 1 A first flowchart of a three-dimensional comprehensive compressibility evaluation method for a tight sandstone reservoir horizontal well according to an embodiment of the present application is schematically shown;

[0063] Figure 2 A second flowchart of a three-dimensional comprehensive compressibility evaluation method for a tight sandstone reservoir horizontal well according to an embodiment of the present application is schematically shown;

[0064] Figure 3 A schematic diagram of the relationship between the natural fracture dip angle of a tight sandstone reservoir and the shut-in pressure gradient is schematically shown;

[0065] Figure 4 A schematic diagram of a horizontal well track passing through a poor sandstone reservoir under a high-quality sandstone reservoir, a mudstone interlayer and a thin interlayer is schematically shown, wherein part (a) is a schematic diagram of a horizontal well track passing through a high-quality sandstone reservoir, part (b) is a schematic diagram of a horizontal well track passing through a mudstone interlayer, part (c) is a schematic diagram of a horizontal well track passing through a poor sandstone reservoir under a thin interlayer, and part (d) is a schematic diagram of a horizontal well track passing through a poor sandstone reservoir under a thick interlayer;

[0066] Figure 5 A longitudinal section schematic diagram of a horizontal well passing through different reservoirs is schematically shown;

[0067] Figure 6 A grid schematic diagram of a geological model around a well along the direction of a horizontal well track is schematically shown;

[0068] Figure 7 A grid diagram of the wellbore geology model perpendicular to the horizontal well trajectory direction is schematically shown;

[0069] Figure 8 A mapping coefficient diagram of the wellbore geology attribute on the layer plane where the horizontal well trajectory is located is schematically shown;

[0070] Figure 9 A horizontal well trajectory diagram of the tight sandstone reservoir in a specific application example is schematically shown;

[0071] Figure 10 A vertical stress profile diagram of the tight sandstone reservoir in a specific application example is schematically shown;

[0072] Figure 11 An evaluation parameter weight diagram obtained based on the grey correlation degree method is schematically shown;

[0073] Figure 12 An evaluation parameter weight diagram obtained based on the analytic hierarchy process method is schematically shown;

[0074] Figure 13 An evaluation parameter weight diagram obtained based on the Pearson method is schematically shown;

[0075] Figure 14 An evaluation parameter weight diagram obtained based on the entropy value method is schematically shown;

[0076] Figure 15 A main control parameter and a corresponding weight in the comprehensive compressibility evaluation parameter of the tight sandstone reservoir in a specific application example are schematically shown;

[0077] Figure 16 A verification result diagram of the comprehensive compressibility evaluation result on a specific production profile test horizontal well is schematically shown;

[0078] Figure 17 A composition block diagram of the three-dimensional comprehensive compressibility evaluation device of the tight sandstone reservoir horizontal well according to the embodiment of the present application is schematically shown;

[0079] Figure 18 A structure block diagram of the computer device according to the embodiment of the present application is schematically shown. DETAILED DESCRIPTION

[0080] The specific embodiments of the embodiments of the present application are described in detail below with reference to the accompanying drawings. It should be understood that the specific embodiments described herein are only used to illustrate and explain the embodiments of the present application, and are not used to limit the embodiments of the present application.

[0081] Embodiment one

[0082] Referring to Figures 1 to 8 The embodiment of the present application provides a three-dimensional comprehensive compressibility evaluation method for a horizontal well in a tight sandstone reservoir, comprising the following implementation steps:

[0083] Step S100, three-dimensional modeling of geological properties around a target horizontal well is performed to obtain a geological model around the well, the geological properties including lithology, natural fractures and oil and gas bearing property.

[0084] Step S200, geological property assignment is performed to distinguish the influence degree of different classifications of each geological property on post-fracturing productivity.

[0085] It is known that after the geological model around the well is constructed by modeling the geological properties around the well, each grid in the model is associated with its corresponding geological property, and the geological property assignment refers to assigning values to the geological properties associated with the grids to distinguish the influence degree of different classifications of each geological property on post-fracturing productivity.

[0086] For a tight sandstone reservoir, the types of lithology usually include high-quality sandstone, poor sandstone and mudstone. Through analysis of field production profile test results, it is shown that high-quality sandstone contributes the most to productivity, poor sandstone takes the second place, and mudstone contributes nothing to productivity. The contribution of different lithology to post-fracturing productivity is from low to high, and different lithology can be assigned with scores from low to high in turn. Single-well post-fracturing analysis results show that natural fractures are the most important factor for controlling the complexity of fracturing fractures and post-fracturing productivity. According to the different development degrees of natural fractures, the tight sandstone reservoir can be generally divided into fault-fracture type, fold-fracture type and matrix type reservoirs. The types of natural fractures usually include fracture development type, relatively developed fracture type and non-developed fracture type. The contribution of different development degrees of natural fractures to post-fracturing productivity is from low to high, and different development degrees of natural fractures can be assigned with scores from low to high in turn. For a horizontal well, post-fracturing water production will lead to rapid water flooding of the entire horizontal section, and it is necessary to consider the oil, gas and water distribution of the formation around the horizontal well. Therefore, the reservoirs with different oil and gas bearing properties should be avoided from being fractured to water layers or gas-water or oil-water layers, and thus the contribution of different oil and gas bearing properties to productivity is from low to high, and different oil and gas bearing properties can be assigned with scores from low to high in turn. Different oil and gas bearing properties include single-phase layer, dry layer and two-phase layer. The single-phase layer is a gas layer or an oil layer, and the two-phase layer is a gas-water layer or an oil-water layer.

[0087] Step S300, fracturing fracture propagation simulation is performed on each passing layer section of the trajectory of the target horizontal well.

[0088] It needs to be understood that the horizontal well trajectory pattern can be given according to the well logging characteristics of the target horizontal well, wherein the well logging characteristics include the while-drilling gamma, well logging lithology, etc. For the tight sandstone reservoir, the trajectory of the horizontal well is divided into different geological sweet spot segments according to different lithology, i.e., the trajectory layer can be a high-quality sandstone trajectory layer, a mudstone trajectory layer and a poor sandstone trajectory layer. In addition, the fracture propagation simulation of each trajectory layer can be performed by using the commercially available fracturing simulation software, and the process of the fracture propagation simulation is not described in detail in this embodiment.

[0089] In step S400, the mapping coefficient is established according to the different fracture height sweep degrees of the fractured fractures, and the geological attribute assignment result is mapped to the horizontal well trajectory according to the mapping coefficient to obtain the wellbore geological sweet spot index.

[0090] In step S500, the main control parameter and the weight in the evaluation parameter including the wellbore geological sweet spot index are obtained to obtain the comprehensive compressibility evaluation result.

[0091] It is mentioned in the background that Baihly and Cipolla et al. proposed that the fracturing section selection should comprehensively consider the geological engineering double sweet spot, and a multi-factor analysis method is used to screen the sensitive factors, and then the weighted calculation is performed to obtain the comprehensive compressibility index of the horizontal well. The above-mentioned horizontal well comprehensive compressibility evaluation method considering the geological engineering double sweet spot has been applied in shale reservoirs. For example, the Chinese patent application with the application number 201910392122.2 discloses a shale gas reservoir fracturing horizontal well compressibility comprehensive evaluation method, mainly including the following implementation steps: S1. Collecting the geological and engineering parameters of the target well area and the post-fracturing productivity data, and selecting the geological and engineering parameters that have a greater impact on the post-fracturing productivity of the shale gas reservoir, wherein the selected geological and engineering parameters are used as the compressibility evaluation index parameters; S2. Forming the compressibility evaluation index parameters into sample data groups that can be used for neural network training and hierarchical analysis, and performing standardization processing on all sample data; S3. Using the neural network method, training and establishing a neural network model with the post-fracturing productivity as the target and the compressibility evaluation index parameters as the analysis object, obtaining the connection weights between the input layer, the hidden layer and the output layer of the neural network; S4. Based on the connection weights of the trained neural network model, calculating the relative importance degrees of the compressibility evaluation index parameters with each other; S5. According to the hierarchical analysis method, using the comprehensive compressibility index values of different shale gas well sections, and investigating the correlation degree between the compressibility index and the post-fracturing productivity.

[0092] It should be understood that, in the present embodiment, after the wellbore geology sweet spot index of the target horizontal well trajectory is obtained through steps S100 to S400 and the wellbore geology sweet spot index is added to the comprehensive compressibility evaluation parameter, how to utilize the evaluation parameter including the wellbore geology sweet spot index to derive the comprehensive compressibility evaluation result is known to one of ordinary skill in the art based on the above-mentioned prior art disclosure, one or more embodiments are known, and at least one feasible embodiment is determined after the embodiments are verified.

[0093] For example, in one specific embodiment, step S500, the comprehensive compressibility evaluation result is derived according to the main control parameters and the weights in the evaluation parameter including the wellbore geology sweet spot index, including the following implementation steps:

[0094] Step S510, other evaluation parameters except the wellbore geology sweet spot index are obtained according to the logging data and the fracturing operation data.

[0095] Step S520, the influence degree of each evaluation parameter on the post-fracturing productivity is analyzed by using the multi-factor analysis method with the productivity maximization as the objective function, and the main control parameters in the evaluation parameter and the weights corresponding to each main control parameter are determined.

[0096] In step S100, the lithology attribute data volume is obtained by lithology modeling, the natural fracture attribute volume is obtained by natural fracture modeling, and the oil and gas bearing saturation attribute volume is obtained by oil and gas bearing modeling. The lithology modeling, the natural fracture modeling and the oil and gas bearing modeling can be obtained by analyzing the seismic data and the logging data collected in the work area where the target horizontal well is located.

[0097] It needs to be understood that in the general embodiment, the lithology can be obtained through comprehensive analysis on parameters such as density, natural gamma, P-S wave velocity ratio, Poisson's ratio, etc. For example, the lithology can be identified according to the P-S wave velocity ratio. Because the Poisson's ratios of different lithology rocks are often different, generally speaking, the Poisson's ratio of mudstone is relatively high, between 1.8-1.9, the Poisson's ratio of siltstone and fine sandstone is relatively low, between 1.66-1.8, and the Poisson's ratio of medium-coarse sandstone is the lowest, between 1.5-1.66. The Poisson's ratio has correlation with the P-S wave velocity ratio, so the lithology is identified through the P-S wave velocity ratio, and the P-S wave velocity ratio data volume can be obtained through rock physics modeling and pre-stack inversion of seismic data. The natural fractures in the tight sandstone reservoir can be identified by using logging data and based on structural identification parameters such as relative abnormality of caliper, three porosity ratio method, secondary porosity ratio method, elastic modulus difference ratio method, resistivity invasion correction difference ratio method and crossplot method, etc. In addition, the maximum likelihood attribute can also be used to identify large faults, which is to scan and calculate the similarity between data points of the entire seismic data volume to obtain the most possible position and probability of fault development in the target section, which can highlight the linear anomaly features related to the fault surface, so as to depict the effect of the fracture. In order to depict the fracture body associated with the fold, the structural entropy attribute can be used to achieve this, which is obtained after obtaining the eigenvalues of three directions based on the gradient structure tensor matrix calculation, reflecting the chaotic reflection caused by the rock layer rupture. In order to depict the fracture body associated with the fold, the curvature attribute can be used to achieve this, which is obtained by participating the amplitude change in the curvature calculation process through the Laplace operator, and identifying the fracture by observing the size change of the amplitude value. Therefore, in order to identify the natural fractures in the tight sandstone reservoir, the above means or their combination can be used. The oil and gas bearing property has correlation with the elastic parameters of the reservoir, so the elastic parameter data volume obtained by AVO attribute or seismic data inversion can be used to identify the oil and gas bearing property of the reservoir. Among them, the elastic parameters that can be used to identify the oil and gas bearing property of the reservoir include Poisson's impedance, etc.

[0098] Exemplarily, after identifying the lithology, natural fractures and oil and gas bearing property of the tight sandstone reservoir, modeling is performed, in a specific embodiment, the geological attribute three-dimensional modeling around the target horizontal well is performed, including the following implementation steps:

[0099] Step S110, identifying the lithology around the target horizontal well according to the P-S wave velocity ratio to obtain the lithology attribute volume;

[0100] Step S120, identifying the natural fractures according to the maximum likelihood attribute, structural entropy attribute and curvature attribute to obtain the natural fracture attribute volume;

[0101] Step S130, identifying the oil and gas bearing property according to the AVO attribute or Poisson's impedance to obtain the oil and gas saturation attribute volume.

[0102] Exemplarily, in one specific embodiment, step S200, geological attribute assignment is performed to distinguish the influence degree of different classifications of each geological attribute on post-fracturing productivity, including the following implementation steps:

[0103] Step S210, different lithology is given a score from low to high according to the contribution degree of different lithology to post-fracturing productivity from low to high;

[0104] Step S220, different natural fracture is given a score from low to high according to the contribution degree of different development degree of natural fracture to post-fracturing productivity from low to high;

[0105] Step S230, different oil and gas bearing property is given a score from low to high according to the contribution degree of different oil and gas bearing property to post-fracturing productivity from low to high.

[0106] For example, the lithology attribute associated with each grid in the wellbore geological model is assigned a score from Table 1, (i, j, k) represents the grid coordinates in the wellbore geological model, which can also be referred to as point coordinates in the wellbore geological model, GRID SAND(i, j, k) represents the lithology assignment result associated with the (i, j, k) grid. The natural fracture attribute associated with each grid in the wellbore geological model is assigned a score from Table 2, GRID FRACTURE(i, j, k) represents the natural fracture assignment result associated with the (i, j, k) grid. The oil and gas bearing property associated with each grid in the wellbore geological model is assigned a score from Table 3, GRID GAS(i, j, k) represents the oil and gas bearing property assignment result associated with the (i, j, k) grid.

[0107] Table 1

[0108]

[0109] Table 2

[0110]

[0111]

[0112] Table 3

[0113]

[0114] Exemplarily, in one specific embodiment, step S300, fracture propagation simulation is performed on each traversing interval of the target horizontal well trajectory, including the following implementation steps:

[0115] Step S310, a formation vertical stress model of the area where the target horizontal well is located is established;

[0116] Step S320, determining each passing layer section according to different lithology passed by the target horizontal well trajectory;

[0117] Step S330, obtaining a vertical stress profile corresponding to each passing layer section by using the formation vertical stress model;

[0118] Step S340, carrying out fracture propagation simulation based on the vertical stress profile.

[0119] It should be understood that the vertical stress profile needs to reflect the lithology change, and therefore, before outputting the vertical stress profile, the grid number can be properly adjusted according to the change of the vertical lithology, so that the finally output vertical stress profile can reflect the lithology change.

[0120] In one specific embodiment, the passing layer section can be a part of the section where the horizontal well passes through various lithology reservoirs, which is a typical section, so as to ensure the comprehensiveness of the fracture propagation simulation while improving the efficiency of the fracture propagation simulation. For example, the typical section can be selected from the upper, middle and lower sections of various geological sweet spot sections, that is, the typical section can include all or part of the upper section of the high-quality sandstone passing layer section, the middle section of the high-quality sandstone passing layer section, the lower section of the high-quality sandstone passing layer section, the upper section of the mudstone passing layer section, the middle section of the mudstone passing layer section, the lower section of the mudstone passing layer section, the upper section of the poor sandstone passing layer section, the middle section of the poor sandstone passing layer section and the lower section of the poor sandstone passing layer section, which is determined in combination with the actual reservoir lithology of the region where the target horizontal well is located.

[0121] In some embodiments, to establish the formation vertical stress model of the region where the target horizontal well is located, the following technical means can be combined: rock triaxial compression experiment method, Brazilian splitting experiment method, geostress calculation model, etc. Among them, the commonly used geostress calculation models include the Kimick model, the Mattarwell-Kelly model, the Huang's model, the spring model and the Gehongkui model, etc.

[0122] For example, step S310, establishing the formation vertical stress model of the region where the target horizontal well is located, includes the following implementation steps:

[0123] Step S3110, determining the conversion relationship between the dynamic rock mechanics parameters and the static rock mechanics parameters of the rock in combination with the actual logging data and the laboratory experimental data under high confining pressure;

[0124] Step S3120, calculating the dynamic rock mechanics parameters of different lithology rocks according to the logging data of the region where the target horizontal well is located, and calculating the static rock mechanics parameters by using the above conversion relationship;

[0125] Step S3130, based on the P-wave and S-wave velocity field and the density field obtained by the geophysical inversion, the geostress field of the region where the target horizontal well is located is calculated;

[0126] Step S3140, using the geostress calculation model, the single-well geostress of the target horizontal well is calculated according to the acoustic logging data.

[0127] Step S3150, taking the single-well geostress as a constraint, the geostress field of the region where the target horizontal well is located is corrected to obtain a formation longitudinal stress model.

[0128] Among them, the laboratory high confining pressure experimental data can be obtained by rock triaxial compression experiment method, Brazilian splitting experiment method, etc., among them, the triaxial compression experiment method can be used to obtain the Young's modulus and Poisson's ratio of different lithology rocks under the geostress condition, and the Brazilian splitting experiment method can be used to obtain the tensile strength of different lithology rocks; when calculating the single-well geostress of the target horizontal well according to the acoustic logging data by using the geostress calculation model, a suitable model can be selected from the geostress calculation models such as the Kimick model, the Matthews-Kelly model, the Huang model, the spring model and the Gehongui model for geostress calculation.

[0129] In the above technical solution, the single-well geostress field is taken as a constraint to correct the geostress field of the region where the target horizontal well is located, so that the accuracy of the constructed formation longitudinal stress model is higher.

[0130] In one specific embodiment, step S400, according to the difference of fracture height and sweep degree of the fractured fracture, a mapping coefficient is established, and the geological attribute assignment result is mapped to the horizontal well trajectory according to the mapping coefficient to obtain a wellbore geological sweet spot index, including the following implementation steps:

[0131] Step S410, according to the difference of fracture height and sweep degree of the fractured fracture, a mapping coefficient is established, and the geological attribute assignment result is mapped to the layer where the horizontal well trajectory is located to obtain a two-dimensional plane attribute. It should be understood that the layer where the horizontal well trajectory is located refers to the plane through which the horizontal well trajectory passes.

[0132] Step S420, the two-dimensional plane attribute is superimposed and assigned to the horizontal well trajectory to obtain the distribution of the wellbore geological sweet spot index along the horizontal well.

[0133] If the length, width and height of the three-dimensional wellbore geological model are represented as L, W and H, the three dimensions are represented as i direction (length direction), j direction (width direction) and k direction (height direction), and the horizontal well trajectory extends along the i direction, then the layer where the horizontal well trajectory is located is the ioj plane. Because the geological properties in the fracture height swept range of the fracturing fracture have different influences on the fracturing of the horizontal well than the geological properties in the unswept range, it is known that the influence of the geological properties in the unswept range of the fracturing fracture on the fracturing of the horizontal well is obviously lower than the influence of the geological properties in the swept range on the fracturing of the horizontal well, so based on this principle, the mapping coefficient is designed to map the three-dimensional geological property assignment results of each grid in the wellbore geological model to the ioj plane. For example, after considering the mapping coefficient, the three-dimensional geological properties of each grid with the same projection point on the ioj plane in the k direction are added up, so as to map the three-dimensional geological properties to two-dimensional plane properties. After mapping the three-dimensional geological properties to two-dimensional plane properties, the two-dimensional geological properties of the grids on the ioj plane are superimposed and assigned to the horizontal well trajectory, that is, to the one-dimensional wellbore corresponding to the horizontal well trajectory. For example: all two-dimensional geological properties of each grid with the same projection point on the horizontal well trajectory in the j direction are added up, so as to map the two-dimensional plane properties to the one-dimensional wellbore.

[0134] Based on the above principle, in one specific embodiment, step S410, according to the different fracture height swept degrees of the fracturing fracture, the mapping coefficient is established, and the geological property assignment results are mapped to the layer where the horizontal well trajectory is located according to the mapping coefficient to obtain two-dimensional plane properties, including the following implementation steps:

[0135] Step S4101, if the vertical distance of a point in the wellbore geological model from the layer where the horizontal well trajectory is located is greater than the half-fracture height of the fracturing fracture at the projection point of the point on the layer where the horizontal well trajectory is located, then the mapping coefficient of the point is determined as a first output value, and the first output value decreases with the increase of the difference between the vertical distance of the point from the layer where the horizontal well trajectory is located and the half-fracture height of the fracturing fracture at the projection point of the point on the layer where the horizontal well trajectory is located.

[0136] Step S4102, if the vertical distance of a point in the wellbore geological model from the layer where the horizontal well trajectory is located is less than or equal to the half-fracture height of the fracturing fracture at the projection point of the point on the layer where the horizontal well trajectory is located, then the mapping coefficient of the point is determined as a first preset value, and the first preset value is greater than any first output value.

[0137] Step S4103, for a certain geological property, the assignment results of each point in the wellbore geological model under the geological property are weighted by using the mapping coefficient, and the weighted results of each grid corresponding to the same projection point on the layer where the horizontal well trajectory is located are added up to obtain superimposed assignment.

[0138] Step S4104, and so on, to obtain the superimposed assignment value corresponding to each geological attribute itself, thereby completing the mapping of the geological attribute assignment result on the layer where the horizontal well trajectory is located, to obtain the two-dimensional planar attribute.

[0139] As a modification of the above embodiment, step S410, according to the different swept degrees of the fracture height of the fracturing fracture, a mapping coefficient is established, and the geological attribute assignment result is mapped onto the layer where the horizontal well trajectory is located according to the mapping coefficient, to obtain the two-dimensional planar attribute, including the following implementation steps:

[0140] Step SS4101, if the vertical distance of a certain point in the wellbore geological model from the layer where the horizontal well trajectory is located is greater than the half-fracture height of the fracturing fracture at the projection point of the layer where the horizontal well trajectory is located, the mapping coefficient of the point is determined as a first output value, and the first output value is the output value obtained by inputting the difference between the vertical distance and the half-fracture height of the fracturing fracture into an exponential decay function.

[0141] Step SS4102, if the vertical distance of a certain point in the wellbore geological model from the layer where the horizontal well trajectory is located is less than or equal to the half-fracture height of the fracturing fracture at the projection point of the layer where the horizontal well trajectory is located, the mapping coefficient of the point is determined as a first preset value, and the first preset value is not less than 1.

[0142] Step SS4103, for a certain geological attribute, the assignment result of each point in the wellbore geological model under the geological attribute is weighted by using the mapping coefficient, and the weighted results of the points corresponding to the same projection point on the layer where the horizontal well trajectory is located are accumulated, to obtain a superimposed assignment value.

[0143] Step SS4104, and so on, to obtain the superimposed assignment value corresponding to each geological attribute itself, thereby completing the mapping of the geological attribute assignment result on the layer where the horizontal well trajectory is located, to obtain the two-dimensional planar attribute.

[0144] In the above embodiment, the mapping coefficient of the point with a vertical distance less than the half-fracture height of the fracturing fracture is uniformly set as a fixed value not less than 1, i.e., the first preset value, which indicates that the geological attributes of these grids have the same influence degree on the fracturing of the horizontal well, and the mapping coefficient of the point with a vertical distance greater than the half-fracture height of the fracturing fracture is exponentially decayed according to the distance from the layer where the horizontal well trajectory is located, i.e., the farther the distance, the more the decay, and correspondingly, the smaller the mapping coefficient. The quantitative description of the above first preset value and first output value realizes the accurate quantitative mapping of the three-dimensional geological attribute to the two-dimensional planar attribute, thereby improving the reliability of the evaluation result of the comprehensive fracturing property of the horizontal well in the tight sandstone reservoir.

[0145] Based on the above principle, in a specific embodiment, step S420, the two-dimensional planar attribute is superimposed to the horizontal well trajectory, to obtain the wellbore geological sweet spot index distribution along the horizontal well, including the following implementation steps:

[0146] In step S4201, for a certain geological attribute, the superimposed values ​​of each point corresponding to the same projection point on the horizontal well trajectory are accumulated to obtain a first accumulated value. Similarly, the first accumulated value of each geological attribute itself at the projection point is obtained, and then the first accumulated value of each geological attribute itself at the projection point is accumulated to obtain the geological sweet spot index around the horizontal well trajectory at the projection point position.

[0147] Step S4202, and so on, to obtain the distribution of geological sweet spot index around the horizontal well.

[0148] For example, suppose a horizontal well extends along direction i; the length of the horizontal section of the horizontal well is represented by L well ; The fracture extends along the j and k directions; the maximum number of grids in the i direction is represented by i max , and i max =L well / i cell ; The minimum number of grids in direction i is represented by i min , and i min =1; the maximum number of grids in the j direction is expressed as j max =W / 2 / j cell ; The minimum number of grids in the j direction is expressed as j min =-W / 2 / j cell ; The maximum number of grids in the k direction is represented by k max =H / 2 / k cell ; The minimum number of grids in the k direction is expressed as k min =-H / 2 / k cell ;i cell 、j cell 、k cell Represent the length, width and height of each grid respectively; k0 represents the longitudinal position of point (i, j) on the horizontal well trajectory; h(L(i, j, k)) represents the vertical distance from the point with coordinates (i, j) projected on the horizontal well trajectory in the well surrounding geological model to the layer where the horizontal well trajectory is located, in m; h(L(i, j, k0)) represents the fracturing simulation half-fracture height at point (i, j) on the layer where the horizontal well trajectory is located, in m.

[0149] The mapping coefficient can be obtained by formula 1:

[0150]

[0151] In formula 1, 1≤i≤i max ,j min ≤j≤j max , k min ≤k≤k maxa represents a preset coefficient greater than 0, preferably ranging from 1 to 2, and the first preset value is 1.

[0152] The two-dimensional plane attributes are obtained through Formulas Two to Four:

[0153]

[0154]

[0155]

[0156] In Formulas Two to Four, GRID_SAND(i,j,k0), GRID_FRACTURE(i,j,k0) and GRID_GAS(i,j,k0) represent the superimposed values of the lithology geological attribute, the superimposed values of the natural fracture geological attribute and the superimposed values of the oil and gas bearing geological attribute, respectively.

[0157] The wellbore geological sweet spot index is calculated through Formula Five:

[0158]

[0159] In Formula Five, and represent the first accumulated values of the lithology geological attribute, the first accumulated values of the natural fracture geological attribute and the first accumulated values of the oil and gas bearing geological attribute, respectively.

[0160] In the prior art, the geological sweet spot related geological parameters and the engineering sweet spot related engineering parameters are considered in the horizontal well comprehensive compressibility evaluation method based on the geological engineering double sweet spots. In order to realize the compressibility evaluation of the horizontal well in the tight sandstone reservoir, the evaluation parameters involved in step S500 are increased by the wellbore geological sweet spot index, which is a geological parameter, and the process parameters. By adding the wellbore geological sweet spot index and the process parameters into the comprehensive compressibility evaluation parameters, the evaluation parameters are more comprehensive, thereby improving the accuracy and reliability of the comprehensive compressibility evaluation results.

[0161] Correspondingly, in step S500, the main control parameters and the weights in the evaluation parameters including the wellbore geological sweet spot index are obtained to obtain the comprehensive compressibility evaluation results, including the following implementation steps:

[0162] In step SS510, the geological parameters, the engineering parameters and the process parameters except the wellbore geological sweet spot index are obtained according to the logging data and the fracturing operation data.

[0163] Step SS520, a multi-factor analysis method is used to analyze the influence degree of the geological parameters, engineering parameters and process parameters on the post-fracturing productivity, taking the productivity maximization as the objective function, to determine the main control parameters in the geological parameters, engineering parameters and process parameters and the corresponding weights of each main control parameter.

[0164] Step SS530, a comprehensive compressibility evaluation result is obtained according to the main control parameters and the corresponding weights.

[0165] For example, in one specific embodiment, the geological parameters other than the wellbore geological sweet spot index include one of the total hydrocarbon of the horizontal wellbore distribution, the drilling fluid loss rate and the fracture development index, one of the porosity, the AC acoustic travel time logging value and the GR measurement value, etc. The engineering parameters include the brittleness index, the minimum horizontal principal stress and the horizontal principal stress difference coefficient, etc. The process parameters include the single-stage sand volume, the single-stage liquid volume, the single-stage displacement and the fracture complexity, etc.

[0166] In combination Figures 9 to 16 As shown in the above embodiment, the tight sandstone reservoir horizontal well three-dimensional comprehensive compressibility evaluation method is used to carry out the comprehensive compressibility evaluation of the target horizontal well (hereinafter referred to as the horizontal well) in a certain block of the Sichuan Basin, and the evaluation process is as follows:

[0167] Step A1, data preparation, the prepared data mainly include drilling and completion data, seismic data, logging data and analysis test data.

[0168] Among them: the drilling and completion data include the pilot hole and the horizontal well drilling geological daily report, the geological daily report mainly involves the drilling trajectory, the drilled lithology, the logging total hydrocarbon and the drilling time, etc. The seismic data include the pre-stack elastic parameter inversion data body, the post-stack result data body, the curvature data body, the maximum likelihood data body, the ant data and the target horizon interpretation data (XYZ format) in the area range of the horizontal well, if the target work area develops faults, the fault interpretation data (XYZ format, stick and polygon) are also included, and the above seismic data all need depth domain data, if it is time domain data, the time-depth relationship data is needed for time-depth conversion; the logging data include the pilot hole and the horizontal well logging interpretation results, the logging interpretation results include the physical property, the oil and gas bearing property, the natural fracture, the rock mechanics parameter and the ground stress parameter, etc.; the analysis test data include the Young's modulus, the Poisson's ratio and the three-dimensional ground stress test results of different types of lithology cores.

[0169] Step A2, three-dimensional modeling of the geological properties around the horizontal well, to obtain the geological model around the well.

[0170] Step A3, classification and assignment of the grid of the geological model around the well.

[0171] Specifically, in the geological modeling software, based on Tables 4 to 6, the wellbore geological model grid is assigned values ​​according to the preset different lithology discrimination conditions, different development levels of natural fracture discrimination conditions, and different gas-bearing strata discrimination conditions. p / V s represents the ratio of longitudinal and transverse wave velocities, and Sg in Table 6 represents gas saturation.

[0172] Table 4

[0173]

[0174] Table 5

[0175]

[0176] Table 6

[0177]

[0178] Step A4: According to the horizontal well logging characteristics, a horizontal well trajectory pattern diagram is given, as shown in the following example: Figure 9 As shown in the figure, the horizontal well enters the high-quality sandstone interval from target I. After traversing 430 m, the lithology changes to mudstone, i.e., it enters the mudstone interval. While traversing the mudstone, the horizontal well trajectory is 1 to 6 m away from the upper high-quality sandstone reservoir. At target II, the mudstone thickness reaches a maximum of approximately 6 m. After traversing the mudstone for 300 m, the horizontal well trajectory enters the sandstone interval, but this interval is located at the bottom of the high-quality sandstone, i.e., it enters the poor sandstone interval.

[0179] Step A5: constructing a vertical stress model of the formation in the area where the horizontal well is located.

[0180] The in-situ stress of a single well can be calculated quickly and intuitively using acoustic logging. Furthermore, since the area where the horizontal well is located is significantly affected by tectonic movement and has diverse lithologies vertically, the combined spring model is preferably used in this application example to calculate the in-situ stress of a single horizontal well. The calculation formula is as follows:

[0181]

[0182] In Formula 6, E s is the static Young's modulus, in MPa; μ s is the static Poisson's ratio; ε H , ε h are the maximum and minimum horizontal structural strain coefficients respectively; α is the Biot coefficient. For the tight sandstone of the Xu 2nd Member of the Qianfoya Formation, predecessors have established a prediction model of the Biot coefficient and the acoustic time difference, namely: α=0.562*ln(AC)-2.6117, AC is the longitudinal wave acoustic time difference, the unit is μs / m. This application example uses this prediction model to calculate the α value; pp Pp is pore pressure; σ v σv is vertical stress, in MPa, which is calculated according to density logging value; σ h σhmin is horizontal minimum stress, in MPa; σ H σhmax is horizontal maximum stress, in MPa.

[0183] The single-point three-way stress values of different lithology rocks are determined by using differential strain experiment method, etc. According to the obtained single-point stress, the horizontal maximum tectonic strain coefficient ε H = 1.1 x 10 -3 and the horizontal minimum tectonic strain coefficient ε h = 0.65 x 10 -3 are inversely calculated in formula one, which can be applied to single-well stress prediction. The single-well stress prediction results of horizontal well are shown in FIG. 1. Figure 10 As shown in the figure, the lithology is divided into high-quality sandstone and mudstone interlayer in the longitudinal direction. The bottom of high-quality sandstone is a low stress area, and the lower part is adjacent to the high stress mudstone interlayer.

[0184] Step A6, the longitudinal stress profile of each passing section of horizontal well trajectory is output by using the formation longitudinal stress model, and the fracture propagation simulation is carried out based on the longitudinal stress profile.

[0185] Specifically, the fracture height simulation results of horizontal well in different passing sections under certain fracturing process parameters are simulated by using fracturing simulation software, as shown in Table Seven. The fracture half-height given in Table Seven is h(L(i0,j0,k0)) in formula one.

[0186] Table Seven

[0187]

[0188]

[0189] Step A7, in the 300, 30m range grid around the horizontal well, the mapping of each geological attribute assignment result in the wellbore geological model on the horizontal well trajectory is calculated one by one by using formula one to formula five, to obtain the wellbore geological sweet spot index along the horizontal well trajectory.

[0190] Step A8, according to the wellbore geological sweet spot index, logging data and fracturing construction data, a comprehensive parameter database of geology-engineering-technology-production effect is established. It is known that the production effect includes open flow capacity, single section oil or gas contribution rate, etc. Figures 11 to 14The influence of tight sandstone reservoir geological parameters, engineering parameters, and process parameters on the transformation volume is given by using the grey correlation degree, hierarchical analysis method, Pearson method, and entropy method in the multi-factor analysis method. Among them, the geological parameters specifically include the wellbore geological sweet spot index, the total hydrocarbon average value ( Figures 11 to 14 The average value of porosity ( Figures 11 to 14 expressed as PORE average value), AC acoustic time difference logging value or GR natural gamma measurement value ( Figures 11 to 14 The engineering parameters specifically include the average brittleness index, horizontal stress difference coefficient, average horizontal minimum principal stress gradient, average brittle mineral content, and pump-off pressure gradient; the process parameters specifically include total liquid volume, total sand volume, liquid intensity, sand addition intensity, and comprehensive sand-to-liquid ratio. After multi-factor analysis, the main control parameters affecting the fracturing effect of tight sandstone were identified as including the wellbore geological sweet spot index, average porosity, AC / GR, average brittle mineral content, average horizontal minimum principal stress gradient, liquid intensity, and comprehensive sand-to-liquid ratio. The weights of these main control parameters were also determined. For example, the weight of a certain main control parameter is the average of the weights of the main control parameter determined by various multi-factor analysis methods. The comprehensive compressibility evaluation results can be calculated based on the determined main control parameters and weights. In this application example, the comprehensive compressibility evaluation results are represented by the comprehensive compressibility index.

[0191] Under the condition that the evaluation parameters only consider geological parameters including the wellbore geological sweet spot index and engineering parameters, the specific steps of step A8 can be as follows:

[0192] Based on the peri-well geological sweet spot index, logging data and fracturing operation data, a comprehensive parameter database of geology, engineering and production effects was established. Through multi-factor analysis, the main control parameters affecting the fracturing effect of tight sandstone reservoirs were identified, including the peri-well geological sweet spot index, drilling fluid loss rate, total hydrocarbon, porosity, AC / GR, horizontal minimum principal stress, brittleness index, stress difference coefficient, and brittle mineral content. The weights of each main control parameter were also clarified, such as Figure 15 As shown;

[0193] Using Formula 7, the comprehensive compressibility evaluation result can be calculated based on the determined main control parameters and weights:

[0194] S = 0.123*peripheral geological sweet spot index + 0.142*drilling fluid loss rate + 0.123*total hydrocarbon + 0.098*AC / GR + 0.069*porosity + 0.141*horizontal minimum principal stress + 0.114*brittleness index + 0.097*stress difference coefficient + 0.093*brittle mineral content (Formula 7);

[0195] In Formula Seven, S represents the comprehensive compressibility index, that is, the comprehensive compressibility evaluation result is represented by the comprehensive compressibility index S.

[0196] Step A9, the obtained comprehensive compressibility index is verified.

[0197] Specifically, the verification is performed on a certain production profile test horizontal well, and the verification result is as shown in Figure 16 As shown in the figure, the comprehensive compressibility index and the production profile coincidence degree reach 83.2%, the production effect is good when the comprehensive compressibility index is greater than 30%, which verifies the effectiveness of the above-mentioned embodiment of the comprehensive compressibility evaluation method of the tight sandstone reservoir horizontal well.

[0198] Example Two

[0199] Referring to Figure 17 The embodiment of the present application also provides a three-dimensional comprehensive compressibility evaluation device 400 of a tight sandstone reservoir horizontal well, which comprises sequentially connected wellbore geological model construction module 410, geological attribute assignment module 420, fracturing fracture propagation simulation module 430, wellbore geological sweet spot index mapping module 440 and comprehensive compressibility evaluation module 450, wherein:

[0200] The wellbore geological model construction module 410 is used for three-dimensional modeling of the geological attributes of the target horizontal well, and a wellbore geological model is obtained, wherein the geological attributes include lithology, natural fractures and oil and gas bearing property;

[0201] The geological attribute assignment module 420 is used for geological attribute assignment to distinguish the influence degree of different classifications of each geological attribute on the post-pressing production capacity;

[0202] The fracturing fracture propagation simulation module 430 is used for fracturing fracture propagation simulation on the passing layer section of the target horizontal well trajectory;

[0203] The wellbore geological sweet spot index mapping module 440 is used for establishing a mapping coefficient according to the different fracture height sweep degrees of the fracturing fractures, and mapping the geological attribute assignment result to the horizontal well trajectory according to the mapping coefficient to obtain a wellbore geological sweet spot index;

[0204] The comprehensive compressibility evaluation module 450 is used for obtaining a comprehensive compressibility evaluation result according to the main control parameters and weights in the evaluation parameters including the wellbore geological sweet spot index.

[0205] In one specific embodiment, the three-dimensional modeling of the geological attributes of the target horizontal well is performed to obtain a wellbore geological model, and the geological attributes include lithology, natural fractures and oil and gas bearing property, which comprises:

[0206] The lithology of the wellbore of the target horizontal well is identified according to the ratio of P-wave velocity to S-wave velocity;

[0207] identify natural fractures according to the maximum likelihood attribute, the structural entropy attribute and the curvature attribute;

[0208] identify oil and gas bearing properties according to AVO attributes or Poisson impedance.

[0209] In one embodiment, the geological property assignment is performed to distinguish the influence degree of different classifications of each geological property on post-fracturing productivity, and the method comprises:

[0210] different lithologies are assigned with scores from low to high according to the contribution degree of different lithologies to post-fracturing productivity, and the types of lithologies include high-quality sandstone, poor sandstone and mudstone;

[0211] different natural fractures are assigned with scores from low to high according to the contribution degree of different development degrees of natural fractures to post-fracturing productivity, and the types of natural fractures include developed natural fractures, relatively developed natural fractures and undeveloped natural fractures;

[0212] different oil and gas bearing properties are assigned with scores from low to high according to the contribution degree of different oil and gas bearing properties to post-fracturing productivity, and different oil and gas bearing formations include single-phase formation, dry formation and two-phase formation, the single-phase formation is gas formation or oil formation, and the two-phase formation is gas-water formation or oil-water formation.

[0213] In one embodiment, the fracturing fracture propagation simulation of the passing interval of the target horizontal well trajectory is performed, and the method comprises:

[0214] establishing a formation vertical stress model of the region where the target horizontal well is located;

[0215] determining different passing intervals according to the different lithologies passed by the target horizontal well trajectory;

[0216] obtaining a vertical stress profile corresponding to the passing interval by using the formation vertical stress model;

[0217] conducting fracturing fracture propagation simulation based on the vertical stress profile.

[0218] In one embodiment, the establishment of the formation vertical stress model of the region where the target horizontal well is located comprises:

[0219] determining the conversion relationship between dynamic rock mechanics parameters and static rock mechanics parameters of rocks by combining actual logging data and laboratory experimental data under high confining pressure;

[0220] calculating dynamic rock mechanics parameters of different lithologies according to logging data of the region where the target well is located, and calculating static rock mechanics parameters by using the conversion relationship;

[0221] Based on the P-wave and S-wave velocity field and the density field obtained by geophysical inversion, the earth stress field of the target horizontal well area is calculated;

[0222] Using the earth stress calculation model, the single well earth stress of the target horizontal well is calculated according to the acoustic logging data;

[0223] Taking the single well earth stress as a constraint, the earth stress field of the target horizontal well area is corrected to obtain the formation longitudinal stress model.

[0224] In one specific embodiment, according to the different fracture height and sweep of the fractured fracture, a mapping coefficient is established, and the geological property assignment result is mapped to the layer where the horizontal well trajectory is located according to the mapping coefficient to obtain a two-dimensional plane attribute.

[0225] According to the different fracture height and sweep of the fractured fracture, a mapping coefficient is established, and the geological property assignment result is mapped to the layer where the horizontal well trajectory is located according to the mapping coefficient to obtain a two-dimensional plane attribute.

[0226] The two-dimensional plane attribute is superimposed and assigned to the one-dimensional wellbore of the horizontal well trajectory to obtain the distribution of the geological sweet spot index around the horizontal well.

[0227] In one specific embodiment, according to the different fracture height and sweep of the fractured fracture, a mapping coefficient is established, and the geological property assignment result is mapped to the layer where the horizontal well trajectory is located according to the mapping coefficient to obtain a two-dimensional plane attribute, including:

[0228] If the vertical distance of a point in the wellbore geological model from the layer where the horizontal well trajectory is located is greater than the fracture simulation half-fracture height at the projection point of the point on the layer where the horizontal well trajectory is located, the mapping coefficient of the point is determined as a first output value, and the first output value is the output value obtained by inputting the difference between the vertical distance and the fracture simulation half-fracture height into an exponential decay function;

[0229] If the vertical distance of a point in the wellbore geological model from the layer where the horizontal well trajectory is located is less than or equal to the fracture simulation half-fracture height at the projection point of the point on the layer where the horizontal well trajectory is located, the mapping coefficient of the point is determined as a first preset value, and the first preset value is not less than 1;

[0230] For a certain geological property, the assignment results of each point in the wellbore geological model in the geological property are weighted using the mapping coefficient, and the weighted results of the points corresponding to the same projection point on the layer where the horizontal well trajectory is located are accumulated to obtain a superimposed assignment.

[0231] By analogy, the superimposed assignment corresponding to each geological property is obtained, so as to complete the mapping of the geological property assignment result on the layer where the horizontal well trajectory is located, and obtain a two-dimensional plane attribute.

[0232] In one embodiment, the superimposed assignment of the two-dimensional plane attribute to the one-dimensional wellbore of the horizontal well track obtains the distribution of the wellbore geology sweet spot index along the horizontal well, including:

[0233] For a certain geology attribute, the superimposed assignments of each point corresponding to the same projection point on the one-dimensional wellbore are accumulated to obtain a first accumulated value, and so on, to obtain the first accumulated value of each geology attribute itself at the projection point, and the first accumulated values of each geology attribute itself at the projection point are summed to obtain the wellbore geology sweet spot index of the one-dimensional wellbore at the projection point position.

[0234] In this way, the distribution of the wellbore geology sweet spot index along the horizontal well is obtained.

[0235] In one embodiment, the evaluation parameters include geology parameters, engineering parameters and process parameters including the wellbore geology sweet spot index.

[0236] In one embodiment, the comprehensive compressibility evaluation result is obtained according to the main control parameter and the weight in the evaluation parameters including the wellbore geology sweet spot index, including:

[0237] According to the logging data and the fracturing operation data, the geology parameters, the engineering parameters and the process parameters except the wellbore geology sweet spot index are obtained.

[0238] Taking the maximum production as the objective function, the influence degree of the geology parameters, the engineering parameters and the process parameters on the production capacity after fracturing is analyzed by using the multi-factor analysis method, and the main control parameter and the corresponding weight are determined.

[0239] The comprehensive compressibility evaluation result is obtained according to the main control parameter and the corresponding weight.

[0240] In one embodiment, the geology parameters except the wellbore geology sweet spot index include one of the total hydrocarbon, the drilling fluid leakage rate and the fracture development index distributed along the wellbore, one of the porosity, the AC acoustic travel time logging value and the GR measurement value.

[0241] In one embodiment, the engineering parameters include the brittleness index, the minimum horizontal principal stress and the horizontal principal stress difference coefficient.

[0242] In one embodiment, the process parameters include the single-stage sand volume, the liquid volume, the displacement, the reconstruction volume and the fracture complexity.

[0243] In another aspect, the embodiments of the present application also provide a machine readable storage medium, which stores a computer program, and the computer program is executed by a processor to implement the above-mentioned various compacted sandstone reservoir horizontal well three-dimensional comprehensive compressibility evaluation method.

[0244] In yet another aspect, the embodiments of the present application also provide a processor, which is used to run a program, wherein the program performs the above-mentioned comprehensive compacted sandstone reservoir horizontal well compressibility evaluation method.

[0245] In yet another aspect, the embodiments of the present application also provide a computer device, which can be a terminal, and the internal structure diagram of the computer device can be as shown in Figure 18 The computer device includes a processor A01, a network interface A02, a display screen A04, an input device A05 and a memory (not shown in the figure) connected through a system bus. The processor A01 of the computer device is used to provide computing and control capabilities. The memory of the computer device includes an internal memory A03 and a non-volatile storage medium A06. The non-volatile storage medium A06 stores an operating system B01 and a computer program B02. The internal memory A03 provides an environment for the operating system B01 and the computer program B02 in the non-volatile storage medium A06 to run. The network interface A02 of the computer device is used to communicate with external terminals through network connection. The computer program is executed by the processor A01 to implement the three-dimensional comprehensive compressibility evaluation method of compacted sandstone reservoir horizontal wells. The display screen A04 of the computer device can be a liquid crystal display screen or an electronic ink display screen. The input device A05 of the computer device can be a touch layer overlaid on the display screen, or can be a key, trackball or touchpad arranged on the shell of the computer device, or can be an external keyboard, touchpad or mouse, etc.

[0246] In one embodiment, the three-dimensional comprehensive compressibility evaluation device 400 of compacted sandstone reservoir horizontal wells provided by the present application can be implemented in the form of a computer program, which can run on a computer device as shown in Figure 18 The memory of the computer device can store various program modules constituting the three-dimensional comprehensive compressibility evaluation device 400 of compacted sandstone reservoir horizontal wells, such as the wellbore geological model construction module 410, the geological attribute assignment module 420, the fracturing fracture propagation simulation module 430, the wellbore geological sweet spot index mapping module 440 and the comprehensive compressibility evaluation module 450 as shown in Figure 17 The computer program constituted by various program modules makes the processor execute the steps in the three-dimensional comprehensive compressibility evaluation method of compacted sandstone reservoir horizontal wells described in the specification.

[0247] Figure 18 The computer device can be connected to a network through a network adapter as shown in Figure 17The well circumference geological model construction module 410 in the illustrated compact sandstone reservoir horizontal well three-dimensional comprehensive compressibility evaluation device 400 performs step S100, the computer device can perform step S200 through the geological attribute assignment module 420, the computer device can perform step S300 through the fracturing fracture propagation simulation module 430, the computer device can perform step S400 through the well circumference geological sweet spot index mapping module 440, and the computer device can perform step S500 through the comprehensive compressibility evaluation module 450.

[0248] The embodiment of the present application also provides a computer program product which, when executed on a data processing device, is adapted to execute a program of the following method steps: performing three-dimensional modeling of geological attributes around a target horizontal well to obtain a well circumference geological model, wherein the geological attributes include lithology, natural fractures and oil and gas bearing property; performing geological attribute assignment to distinguish the influence degree of different classifications of each geological attribute on fracturing productivity; performing fracturing fracture propagation simulation on a passing layer section of a target horizontal well trajectory; establishing a mapping coefficient according to different fracture height sweep degrees of the fracturing fractures, and mapping the geological attribute assignment result to the horizontal well trajectory according to the mapping coefficient to obtain a well circumference geological sweet spot index; and obtaining a comprehensive compressibility evaluation result according to a main control parameter and a weight in evaluation parameters including the well circumference geological sweet spot index.

[0249] Those skilled in the art should understand that the embodiments of the present application can be provided as a method, a system or a computer program product. Therefore, the present application can adopt a completely hardware embodiment, a completely software embodiment or an embodiment combining software and hardware aspects. Moreover, the present application can adopt a computer program product implemented on one or more computer usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer usable program codes.

[0250] It should also be noted that the terms "comprising", "including", or any other variant thereof are intended to cover non-exclusive inclusion, so that processes, methods, articles or devices including a series of elements not only include those elements, but also include other elements not explicitly listed, or further include elements inherent in such processes, methods, articles or devices. Without more limitations, the element defined by the statement "including a" does not exclude the presence of another identical element in the process, method, article or device including the element.

[0251] The above is only an embodiment of the present application and is not intended to limit the present application. The present application can have various modifications and changes for those skilled in the art. Any modification, equivalent replacement, improvement, etc. within the spirit and principle of the present application shall be included in the scope of claims of the present application.

Claims

1. A method for three-dimensional comprehensive compressibility evaluation of horizontal wells in tight sandstone reservoirs, characterized in that, The method comprises: carrying out three-dimensional modeling of geological properties around a target horizontal well to obtain a geological model around the well, the geological properties including lithology, natural fractures and oil and gas bearing property; carrying out geological property assignment to distinguish the influence degree of different classifications of each geological property on post-fracturing productivity; carrying out fracturing fracture propagation simulation on a passing layer section of the target horizontal well trajectory; establishing a mapping coefficient according to different fracture height sweep degrees of the fracturing fractures, and mapping the geological property assignment result to the horizontal well trajectory according to the mapping coefficient to obtain a geological sweet spot index around the well; obtaining a comprehensive compressibility evaluation result according to a main control parameter and a weight in evaluation parameters including the geological sweet spot index around the well.

2. The method of claim 1, wherein the method is a method of evaluating the 3D comprehensive compressibility of a tight sandstone reservoir horizontal well, characterized in that, The carrying out three-dimensional modeling of geological properties around a target horizontal well to obtain a geological model around the well comprises: identifying lithology around the target horizontal well according to a ratio of P-wave velocity to S-wave velocity; identifying natural fractures according to maximum likelihood attributes, structural entropy attributes and curvature attributes; identifying oil and gas bearing property according to AVO attributes or Poisson impedance.

3. The method of claim 1, wherein the method is a method of evaluating the 3D comprehensive compressibility of a tight sandstone reservoir horizontal well, characterized in that, The carrying out geological property assignment to distinguish the influence degree of different classifications of each geological property on post-fracturing productivity comprises: according to the contribution degree of different lithologies to post-fracturing productivity from low to high, assigning different lithologies with scores from low to high, the types of lithology including high-quality sandstone, poor sandstone and mudstone; according to the contribution degree of different development degrees of natural fractures to post-fracturing productivity from low to high, assigning different natural fractures with scores from low to high, the types of natural fractures including development type natural fractures, relatively development type natural fractures and non-development type natural fractures; according to the contribution degree of different oil and gas bearing properties to post-fracturing productivity from low to high, assigning different oil and gas bearing properties with scores from low to high, different oil and gas bearing formations including single-phase layer, dry layer and two-phase layer, the single-phase layer being a gas layer or an oil layer, and the two-phase layer being a gas-water layer or an oil-water layer.

4. The method of claim 1, wherein the method is a method of evaluating the 3D comprehensive compressibility of a tight sandstone reservoir horizontal well, characterized in that, The carrying out fracturing fracture propagation simulation on a passing layer section of the target horizontal well trajectory comprises: establishing a formation vertical stress model of a region where the target horizontal well is located; determining different passing layer sections according to different lithologies through which the target horizontal well trajectory passes; obtaining a vertical stress profile corresponding to the passing layer sections by using the formation vertical stress model; carrying out fracturing fracture propagation simulation based on the vertical stress profile.

5. The method of claim 4, wherein the method further comprises, The establishing a formation vertical stress model of a region where the target horizontal well is located comprises: determining a conversion relationship between dynamic rock mechanics parameters and static rock mechanics parameters of rock in combination with actual logging data and laboratory experimental data under high confining pressure; calculating dynamic rock mechanics parameters of rocks of different lithologies according to logging data of a region where the target well is located, and calculating static rock mechanics parameters by using the conversion relationship; calculating a geostress field of the region where the target horizontal well is located based on a P-wave velocity field and a density field obtained by geophysical inversion; calculating single-well geostress of the target horizontal well according to acoustic logging data by using a geostress calculation model; correcting the geostress field of the region where the target horizontal well is located by taking the single-well geostress as a constraint to obtain the formation vertical stress model.

6. The method of claim 1, wherein the method is a method of evaluating the 3D comprehensive compressibility of a tight sandstone reservoir horizontal well, characterized in that, The mapping coefficient is established according to the different fracture heights of the fractured cracks, and the geological attribute assignment result is mapped to the layer where the horizontal well trajectory is located according to the mapping coefficient, so as to obtain the two-dimensional plane attribute. The mapping coefficient is established according to the different fracture heights of the fractured cracks, and the geological attribute assignment result is mapped to the layer where the horizontal well trajectory is located according to the mapping coefficient, so as to obtain the two-dimensional plane attribute. The two-dimensional plane attribute is superimposed and assigned to the one-dimensional wellbore of the horizontal well trajectory, so as to obtain the distribution of the wellbore geological sweet spot index along the horizontal well.

7. The method of claim 6, wherein the method further comprises, The mapping coefficient is established according to the different fracture heights of the fractured cracks, and the geological attribute assignment result is mapped to the layer where the horizontal well trajectory is located according to the mapping coefficient, so as to obtain the two-dimensional plane attribute, including: If the vertical distance of a point in the wellbore geological model from the layer where the horizontal well trajectory is located is greater than the fracture simulation half-fracture height at the projection point of the point on the layer where the horizontal well trajectory is located, the mapping coefficient of the point is determined as a first output value, and the first output value is an output value obtained by inputting the difference between the vertical distance and the fracture simulation half-fracture height into an exponential decay function; If the vertical distance of a point in the wellbore geological model from the layer where the horizontal well trajectory is located is less than or equal to the fracture simulation half-fracture height at the projection point of the point on the layer where the horizontal well trajectory is located, the mapping coefficient of the point is determined as a first preset value, and the first preset value is not less than 1; For a certain geological attribute, the assignment results of the points in the wellbore geological model in the geological attribute are weighted by using the mapping coefficient, and the weighted results of the points corresponding to the same projection point on the layer where the horizontal well trajectory is located are accumulated, so as to obtain the superimposed assignment. By analogy, the superimposed assignment corresponding to each geological attribute itself is obtained, so as to complete the mapping of the geological attribute assignment result on the layer where the horizontal well trajectory is located, and obtain the two-dimensional plane attribute.

8. The method of claim 7, wherein the method further comprises, The two-dimensional plane attribute is superimposed and assigned to the one-dimensional wellbore of the horizontal well trajectory, so as to obtain the distribution of the wellbore geological sweet spot index along the horizontal well. For a certain geological attribute, the superimposed assignments of the points corresponding to the same projection point on the one-dimensional wellbore are accumulated to obtain a first accumulated value, and by analogy, the first accumulated values of each geological attribute itself at the projection point are obtained, and the first accumulated values of each geological attribute itself at the projection point are summed to obtain the wellbore geological sweet spot index of the one-dimensional wellbore at the projection point position. By analogy, the distribution of the wellbore geological sweet spot index along the horizontal well is obtained.

9. The method of claim 1, wherein the method is a method of evaluating the 3D comprehensive compressibility of a tight sandstone reservoir horizontal well, characterized in that, The evaluation parameters include geological parameters, engineering parameters and process parameters including the wellbore geological sweet spot index.

10. The method of claim 9, wherein the method is a method of evaluating the 3D comprehensive compressibility of a tight sandstone reservoir horizontal well, characterized in that, The comprehensive compressibility evaluation result is obtained according to the main control parameter and the weight in the evaluation parameters including the wellbore geological sweet spot index, including: Geological parameters, engineering parameters and process parameters except the wellbore geological sweet spot index are obtained according to logging data and fracturing operation data; A multi-factor analysis method is used to analyze the influence degree of the geological parameters, engineering parameters and process parameters on the post-fracturing productivity, and the main control parameter and the corresponding weight are determined, with the maximum production as the objective function; The comprehensive compressibility evaluation result is obtained according to the main control parameter and the corresponding weight.

11. The method of claim 9, wherein the method is a method of evaluating the 3D comprehensive compressibility of a tight sandstone reservoir horizontal well, characterized in that, The geological parameters other than the wellbore geological sweet spot index include one of total hydrocarbon, drilling fluid leakage rate and fracture development index distributed along the wellbore, one of porosity, AC acoustic travel time logging value and GR measurement value.

12. The method of claim 9, wherein the method is a method of evaluating the 3D comprehensive compressibility of a tight sandstone reservoir horizontal well, characterized in that, The engineering parameters include a brittleness index, a minimum horizontal principal stress and a horizontal principal stress difference coefficient.

13. The method of claim 9, wherein the method is a method of evaluating the 3D comprehensive compressibility of a tight sandstone reservoir horizontal well, characterized in that, The process parameters include single-stage sand volume, fluid volume, displacement, reformation volume and fracture complexity.

14. A compacted sandstone reservoir horizontal well three-dimensional integrated compressibility evaluation device, characterized in that, The device comprises: a wellbore geological model construction module for performing three-dimensional modeling of geological properties of a target horizontal well, to obtain a wellbore geological model, the geological properties including lithology, natural fractures and oil and gas bearing property; a geological property assignment module for assigning geological properties to distinguish the influence degree of different classifications of each geological property on post-frac productivity; a fracturing fracture propagation simulation module for simulating fracturing fracture propagation in a layer segment passed through by a target horizontal well trajectory; a wellbore geological sweet spot index mapping module for establishing a mapping coefficient according to different fracture height sweep degrees of fracturing fractures, and mapping the geological property assignment result to the horizontal well trajectory according to the mapping coefficient, to obtain a wellbore geological sweet spot index; a comprehensive fracturability evaluation module for obtaining a comprehensive fracturability evaluation result according to main control parameters and weights in evaluation parameters including the wellbore geological sweet spot index.

15. A computer device comprising a memory, a processor, and a computer program stored on the memory and executable on the processor, characterized in that, The processor executes the program to implement the method for three-dimensional comprehensive fracturability evaluation of a tight sandstone reservoir horizontal well according to any one of claims 1 to 13.

16. A machine-readable storage medium having stored thereon a computer program, characterized in that, The computer program is executed by the processor to implement the method for three-dimensional comprehensive fracturability evaluation of a tight sandstone reservoir horizontal well according to any one of claims 1 to 13.

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