Fracturing optimization method for full horizontal well section, control device and storage medium

Abstract

The embodiment of the invention provides a fracturing optimization method for a full horizontal well section, a control device and a storage medium, and belongs to the technical field of oil and gas field development. The fracturing optimization method comprises the following steps: constructing a hydraulic fracturing model of a reservoir in a preset area; a fracture network formed by hydrofracture in the hydrofracture model is embedded into the oil and gas reservoir dynamic flow model in an unstructured grid mode, and an oil reservoir numerical simulation model is obtained; by setting fracture development degree parameters and fracturing parameters of a target horizontal well, full-horizontal-well-section development simulation is conducted on the reservoir numerical simulation model, and the optimal fracturing parameters are determined by predicting the yield within the preset time. The fractured reservoir geological engineering integration and full horizontal well section fracturing crack simulation method based on the geological model is formed, based on the method, the fractured reservoir horizontal well staged fracturing construction scheme can be determined, and the horizontal well transformation effect is improved.

Description

Technical Field

[0001] This invention relates to the field of oil and gas field development technology, and more specifically to a fracturing optimization method, control device and storage medium for all horizontal well sections. Background Technology

[0002] Unconventional resources such as shale oil and gas and tight oil and gas are characterized by low porosity and ultra-low permeability in their reservoirs. For enhancing production in these reservoirs, horizontal well staged fracturing technology is often used. However, in the presence of well-developed natural fractures, hydraulic fracturing fractures and natural fractures can interfere with each other, affecting the final hydraulic fracturing effect. For simulation methods of fracture propagation in fractured reservoirs, there are, for example: (1) Discrete element method. The discrete element method is widely used in early fracture simulation and is relatively easy to implement. However, the fracture morphology is limited by the element mesh division and cannot simulate the fracture propagation simulation outside the independent mesh in homogeneous elastic materials; (2) Boundary element method. The boundary element method is also very common in simulating fracture propagation, but it is very difficult to add heterogeneous bodies (e.g., natural fractures) to the model. In addition, this method generates a complete matrix, which is computationally intensive and not conducive to simulating the propagation of multiple fractures; (3) Finite element method. The finite element method requires re-dividing the element mesh for the simulation of fracture propagation, especially the simulation of fracture turning. In addition, this method involves data transfer between different mesh divisions, which is computationally intensive and has poor convergence; (4) Extended finite element method. The extended finite element method allows discontinuous bodies, for example, fractures propagating independently of the mesh division. Therefore, fractures can cross the element instead of propagating along the edge of the element as in other methods. Because the element can be cut, the fracture propagation morphology is variable and is no longer affected by the mesh division shape.

[0003] After fracturing of fractured reservoirs, the flow model changes, and the flow becomes more complex, requiring simplification into an equivalent model for development simulation. Models used for simulating production capacity after fracturing of fractured reservoirs include: (1) Equivalent continuous medium model: This model is based on the flat plate theory and introduces an equivalent permeability tensor, averaging the fractures in the reservoir across the entire reservoir area. However, this model has limitations in production capacity simulation, requiring the existence of a unit volume representation and a symmetric positive definite equivalent permeability tensor. (2) Fractal model: The application of this model is still in its early stages. (3) Discrete fracture model: This model adopts a dimensionality reduction approach to study the fluid flow patterns within fractures, using an n-1 dimensional fracture grid within an n-dimensional reservoir space. The discrete fracture model divides the grid into a grid space and a computational space, reducing the number of grid divisions and significantly improving the model's computational speed. (4) Dual medium model: This model shows that the medium consists of two parallel systems: fractures and bedrock. Each grid in the space corresponds to two sets of porosity, two sets of permeability, two sets of pressure, and two sets of seepage velocities. Two systems are distributed throughout fractured reservoirs, where bedrock and fractures coexist in any grid of the reservoir. The interaction between these two systems can be described by the crossflow coefficient.

[0004] In summary, current research on horizontal well fracturing in fractured oil and gas reservoirs primarily focuses on the impact of the interaction between hydraulic and natural fractures on the network fracture, optimizing fracturing parameters based on the volume and area of ​​the fractured segment. Numerous simulation methods have also been developed for studying the post-fracturing productivity of horizontal wells in fractured oil and gas reservoirs, allowing for the determination of optimal fracture morphology through production comparisons. However, simulations of horizontal well fracturing and post-fracturing development in fractured oil and gas reservoirs still have many shortcomings. Summary of the Invention

[0005] The purpose of this invention is to provide a fracturing optimization method for all horizontal well sections. This method can solve many shortcomings in horizontal well fracturing and post-fracturing development simulation for fractured oil and gas reservoirs.

[0006] To achieve the above objectives, embodiments of the present invention provide a fracturing optimization method for all horizontal well sections. The method includes: constructing a hydraulic fracturing model of the reservoir in a preset area based on geological data, logging data, and coherence data; embedding the fracture network formed by hydraulic fracturing in the hydraulic fracturing model into a dynamic flow model of the oil and gas reservoir using an unstructured mesh to obtain a reservoir numerical simulation model; and performing development simulations of the entire horizontal well section of the reservoir numerical simulation model by setting fracture development parameters and fracturing parameters for the target horizontal well, and determining the optimal fracturing parameters by predicting production within a preset time period.

[0007] Optionally, the step of constructing a hydraulic fracturing model of the reservoir in the preset area based on geological data, well logging data, and coherence data of the preset area includes: constructing a geological model based on the geological data, which includes structural bedding planes, lithofacies, and fault data of the preset area; embedding reservoir properties, geostress, and natural fracture distribution characteristics into the geological model using the well logging data and the coherence data; and constructing the hydraulic fracturing model based on the geological model with embedded characteristics to simulate the interaction between the main fracture and natural fractures, complex hydraulic fracture morphology, stress interference between multiple fractures, and proppant migration within the fractures.

[0008] Optionally, after constructing the hydraulic fracturing model, the fracturing optimization method for the entire horizontal well section further includes: acquiring construction data, the construction data including construction parameters, pump shutdown pressure and construction curve of the horizontal well after fracturing in the preset area; and correcting the geological model and the hydraulic fracturing model based on the construction data.

[0009] Optionally, after obtaining the reservoir numerical simulation model, the fracturing optimization method for the entire horizontal well section further includes: based on the reservoir numerical simulation model, locally refining the hydraulic fractures and natural fractures around the fractured horizontal well; and using the actual production data of the fractured horizontal well to fit the reservoir numerical simulation model to correct the reservoir numerical simulation model.

[0010] Optionally, after obtaining the reservoir numerical simulation model, the fracturing optimization method for the entire horizontal well section further includes: performing fracturing parameter sensitivity analysis on the reservoir numerical simulation model to determine the fracturing parameters and their corresponding design parameters, wherein the fracturing parameters include the number of fracturing segments and the corresponding fracturing segment length.

[0011] Optionally, the fracturing parameters may also include one or more of the following: natural fracture density, fracture spacing, fracturing fluid volume proppant dosage, displacement, and total proppant dosage.

[0012] Optionally, the step of setting fracture development parameters and fracturing parameters for the target horizontal well and performing full-horizontal well section development simulation on the reservoir numerical simulation model includes: embedding discrete natural fracture networks corresponding to different fracture development parameters into the reservoir numerical simulation model based on constant bottom-hole flow pressure conditions; and embedding different fracturing parameters into the reservoir numerical simulation model for different fracture development parameters to perform full-horizontal well section development simulation and predict the production within the corresponding preset time period.

[0013] Optionally, determining the optimal fracturing parameters by predicting the production within a preset time period includes: grouping the fracture development degree parameters into a group, comparing the production increment within the preset time period after performing full-horizontal well section development simulation under different fracturing parameters, and identifying the fracturing parameter corresponding to the highest production increment within the preset time period as the optimal fracturing parameter under that fracture development degree parameter.

[0014] This invention also provides a control device, which includes a memory, a processor, and a computer program stored in the memory and executable on the processor. The processor executes the computer program to implement the above-described fracturing optimization method for all horizontal well sections.

[0015] This invention also provides a machine-readable storage medium storing instructions that cause a machine to execute the aforementioned fracturing optimization method for all horizontal well sections.

[0016] Through the above technical solution, this invention constructs a hydraulic fracturing model for a pre-defined reservoir region; embeds the fracture network formed by hydraulic fracturing in the hydraulic fracturing model into a dynamic flow model of the oil and gas reservoir using an unstructured mesh, thus obtaining a numerical simulation model of the reservoir; and simulates the development of the entire horizontal well section by setting fracture development parameters and fracturing parameters for the target horizontal well, determining the optimal fracturing parameters by predicting production within a pre-defined time period. This forms an integrated geological engineering method for fractured reservoirs based on a geological model, simulating fracturing in the entire horizontal well section. Based on this method, this invention can determine the segmented fracturing construction scheme for horizontal wells in fractured reservoirs, improving the horizontal well stimulation effect. This invention has significant guiding significance for improving the horizontal well fracturing effect of unconventional resources such as fractured shale oil and gas and tight gas.

[0017] Other features and advantages of the embodiments of the present invention will be described in detail in the following detailed description section. Attached Figure Description

[0018] The accompanying drawings are provided to further illustrate embodiments of the present invention and form part of the specification. They are used together with the following detailed description to explain the embodiments of the present invention, but do not constitute a limitation thereof. In the drawings:

[0019] Figure 1 This is a schematic flowchart of the fracturing optimization method for all horizontal well sections provided in an embodiment of the present invention;

[0020] Figure 2 This is a flowchart illustrating an example of a fracturing optimization method for all horizontal well sections;

[0021] Figure 3 This is a schematic diagram of an example geological model;

[0022] Figure 4 This is a schematic diagram of a reservoir numerical simulation model for post-pressure production in a horizontal well with localized mesh refinement.

[0023] Figure 5 This is a schematic diagram of a fracture simulation with different fracture section lengths at different stages of fracture development;

[0024] Figure 6 This is a schematic diagram showing the ratio of production increase corresponding to different fracturing section lengths under moderate fracture development conditions in the example.

[0025] Figure 7 This is a schematic diagram illustrating the ratio of post-fracturing production to different fracturing stage displacements; and

[0026] Figure 8 This is a schematic diagram of fracture morphology when the number of fracturing stages is increased in a high fracture density reservoir with the same total support dose. Detailed Implementation

[0027] The specific embodiments of the present invention will be described in detail below with reference to the accompanying drawings. It should be understood that the specific embodiments described herein are for illustration and explanation only and are not intended to limit the scope of the present invention.

[0028] Current research on horizontal well fracturing in fractured oil and gas reservoirs primarily focuses on the impact of the interaction between hydraulic and natural fractures on the network fracture, optimizing fracturing parameters based on the volume and area of ​​the fractured section. Numerous simulation methods have also been developed for studying the post-fracturing productivity of fractured oil and gas reservoirs, allowing for the determination of optimal fracture morphology through production comparisons. However, simulations of horizontal well fracturing and post-fracturing development in fractured oil and gas reservoirs still have many shortcomings. For example, the aforementioned simulation methods for fracture propagation in fractured reservoirs all involve optimizing single-section horizontal well fracturing, without considering the optimization of fracturing parameters across the entire well section. Furthermore, the aforementioned simulations of post-fracturing productivity in fractured reservoirs do not transfer the resulting fracture morphology to the productivity model for analysis, resulting in horizontal well fracturing optimization parameters that lack specificity. For fractured reservoirs with varying degrees of fracture development, the density and orientation of fractures along the horizontal section differ significantly, greatly impacting hydraulic fracture morphology and horizontal well production. Applying homogeneous models or single-section fracturing optimization cannot fully represent the optimal fracturing parameters for the entire well section, and a complete and reliable design method has not yet been established. Therefore, this invention provides a fracturing optimization method for the entire horizontal well section.

[0029] Figure 1This is a flowchart illustrating the fracturing optimization method for all horizontal well sections provided in this embodiment of the invention. Please refer to it. Figure 1 The fracturing optimization method for all horizontal well sections may include the following steps:

[0030] Step S110: Based on the geological data, well logging data and coherence data of the preset area, construct a hydraulic fracturing model of the reservoir in the preset area.

[0031] Preferably, step S110 may include steps S111-S113.

[0032] Step S111: Construct a geological model based on the geological data.

[0033] The geological data includes structural bedding planes, lithofacies, and fault data for the preset area.

[0034] Please refer to Figure 2 For example, a geological model of an unconventional target reservoir is established based on data such as structural bedding, lithofacies, and faults. Figure 3 As shown, the geological model also includes characteristic parameters such as the trajectory of horizontal wells.

[0035] Step S112: Using the well logging data and the coherence data, embed reservoir properties, geostress, and natural fracture distribution characteristics into the geological model.

[0036] Following the above example, reservoir properties, geostress, and natural fracture distribution characteristics are assigned to the geological model by combining data from well logging and coherence analysis. For example, this may include parameters such as porosity, permeability, pore pressure, Young's modulus, breaking ratio, hydrocarbon saturation, maximum and minimum horizontal well principal stresses, and the angle, length, and spacing distribution of natural fractures, to construct the geological and stress model and fracture distribution model. Figure 3 As shown, the geological model after embedding features also includes attributes such as discrete fracture networks.

[0037] Step S113: Based on the geological model with embedded features, construct the hydraulic fracturing model to simulate the interaction between the main fracture and natural fractures, complex hydraulic fracture morphology, stress interference between multiple fractures, and proppant migration within the fractures.

[0038] Following the example above, a hydraulic fracturing model is established based on the geological model to simulate the interaction between the main fracture and natural fractures, the complex hydraulic fracture morphology, stress interference between multiple fractures, and proppant migration within the fractures.

[0039] Preferably, after step S110, the fracturing optimization method for the entire horizontal well section may further include: acquiring construction data, the construction data including construction parameters, pump shutdown pressure and construction curve of the horizontal well after fracturing in the preset area; and correcting the geological model and the hydraulic fracturing model based on the construction data.

[0040] Following the example above, for the aforementioned hydraulic fracturing model, the geological model and hydraulic fracturing model are calibrated using the previously fracturing horizontal well construction parameters, pump shutdown pressure, and construction curves. This corrects the distribution of natural fractures in the reservoir, the magnitude of geostress, and the difference coefficient, determining whether the established model conforms to the actual situation of the preset area. Furthermore, by fitting the instantaneous pump shutdown pressure and the post-pump shutdown filtration pressure, the fitting accuracy can be controlled within a preset range (e.g., 10%), thus determining the accuracy of the established hydraulic fracturing model for complex fracture propagation.

[0041] Step S120: The fracture network formed by hydraulic fracturing in the hydraulic fracturing model is embedded into the dynamic flow model of the oil and gas reservoir through an unstructured mesh to obtain the numerical simulation model of the oil reservoir.

[0042] Please refer to Figure 2 For example, the hydraulic fracturing model established in step S110 can be embedded into the dynamic flow model of the oil and gas reservoir using an unstructured mesh to obtain a numerical simulation model of the oil reservoir.

[0043] Preferably, after step S120, the fracturing optimization method for the entire horizontal well section may further include: based on the reservoir numerical simulation model, locally refining the hydraulic fractures and natural fractures around the fractured horizontal well; and fitting the reservoir numerical simulation model using the actual production data of the fractured horizontal well to correct the reservoir numerical simulation model.

[0044] Following the example above, to improve the accuracy of production prediction in reservoir numerical simulation models, the mesh of the reservoir surrounding the horizontal well and the hydraulic and natural fractures in the water-oil reservoir numerical simulation model is refined. This better characterizes the parameters of hydraulic and natural fractures and facilitates the simulation of their interaction. For example, an old well that has been producing for N (e.g., N=5) years is selected around a fractured horizontal well. Figure 4The trajectories of the pre-fracturing production well W1 and the fractured horizontal well W2 are shown. To confirm that the established reservoir numerical simulation model conforms to actual fracturing and reservoir conditions, the model can be fitted. For example, the actual production rates of adjacent reservoir production wells can be used for fitting. The fitting parameters can include parameters such as the reduction in fracture conductivity due to proppant embedding and fracturing, and reservoir permeability. The fitting time for production is N years (e.g., N=5) to ensure that the production rate better reflects the fracturing effect.

[0045] Step S130: By setting the fracture development degree parameters and fracturing parameters of the target horizontal well, the development simulation of the entire horizontal well section of the reservoir numerical simulation model is carried out, and the optimal fracturing parameters are determined by predicting the production within a preset time.

[0046] Preferably, prior to step S130, the fracturing optimization method for the entire horizontal well section may further include: performing fracturing parameter sensitivity analysis on the reservoir numerical simulation model to determine the fracturing parameters and their corresponding design parameters. The fracturing parameters include the number of fracturing segments and the corresponding fracturing segment lengths.

[0047] The preferred fracturing parameters in the embodiments of the present invention may also include one or more of the following: natural fracture density, fracture spacing, fracturing fluid volume proppant dosage, displacement, and total proppant dosage.

[0048] Using examples, we analyze the sensitivity of fracturing parameters in horizontal wells of fractured reservoirs to determine pressure parameters and design parameters suitable for different geological and engineering conditions. For example, Table 1 shows the fracturing parameters and their corresponding design parameters.

[0049] Table 1. Example fracturing parameters and design parameters for horizontal well fracturing in fractured reservoirs.

[0050] fracturing parameters Design parameters Fracturing section length (m) 50,100,150,300 Natural crack density None, Low, Medium, High Supportive dose (m3 / segment) 50，75，100 Displacement (m³ / min) 4,6 Total supportive dose (m3) 750

[0051] Following the example above, the fracture development degree parameters and the fracturing parameters and design parameters shown in Table 1 are input into the reservoir numerical simulation model to simulate the development of the entire horizontal well section. The trend of production increase is compared to determine the optimal fracturing parameters and corresponding design parameters.

[0052] Preferably, the step of setting fracture development parameters and fracturing parameters for the target horizontal well and performing full-horizontal well section development simulation on the reservoir numerical simulation model may include: embedding discrete natural fracture networks corresponding to different fracture development parameters into the reservoir numerical simulation model based on a constant bottom-hole flow pressure condition; and embedding different fracturing parameters into the reservoir numerical simulation model for different fracture development parameters to perform full-horizontal well section development simulation and predict the production rate within the corresponding preset time period.

[0053] More preferably, the step of determining the optimal fracturing parameters by predicting the production within a preset time period includes: grouping the fracture development degree parameters into a group, comparing the production increment within the preset time period after performing full-horizontal well section development simulation under different fracturing parameters, and determining the fracturing parameter corresponding to the highest production increment within the preset time period as the optimal fracturing parameter under that fracture development degree parameter.

[0054] The following examples embed different fracturing parameters into reservoir numerical simulation models to simulate the development of the entire horizontal well section, in order to determine the optimal fracturing parameters by predicting the production rate within a preset time.

[0055] Please refer to Figure 5 Taking the fracturing parameter as the fracturing section length as an example, the fracturing morphology of the reservoir numerical simulation model is shown when the fracturing section length is 300m, 150m, 100m and 50m, respectively, under different (natural) fracture development degrees. In order to highlight the fracture display effect, the mesh of hydraulic fracture and natural fracture is not shown in the simulation result figure, and only the post-fracturing fracture location and morphology are listed separately.

[0056] The reservoir numerical simulation model was developed using a constant bottom-hole flowing pressure method. The baseline scenario was set under various natural fracture density conditions, with the target well not fractured. Under various fractured conditions, the production rate was compared with the production rate under the baseline scenario, serving as a standard for determining fracture parameters.

[0057] Following the example above, this section analyzes the degree of production improvement achieved by different fracturing section lengths under varying fracture development levels. Please refer to [reference needed]. Figure 6 The figure shows the ratio of increased production to production without hydraulic fracturing under moderate fracture development conditions, with different fracturing stage lengths and numbers. The figure indicates that the more fracturing stages, the higher the increased oil production. This trend is consistent for reservoirs with various fracture development levels, only the degree of production increase differs.

[0058] Furthermore, Table 2 shows the production increase of fractured wells after 5 years under different conditions of natural fracture development, based on the numerical simulation model of reservoir development, with varying fracture lengths and numbers of fractured sections. The table shows that the production increase is directly proportional to the number of fractured sections and inversely proportional to the degree of natural fracture development. The relationship between the production increase trend and the number of fractured sections is not linear, but the production improvement effects of 6 and 8 fractured sections are very similar. That is, when the number of fractured sections is greater than 8, the average effect of each section on production improvement is no longer significant, and the return on investment in fracturing decreases.

[0059] Table 2. Production increase under different fracture development conditions with different fracturing section lengths and number of sections.

[0060]

[0061]

[0062] To investigate the impact of displacement on fracturing effectiveness, two scenarios were used: low and high fracture development levels. The displacement was 100m³ per segment. 3 At that time, compare displacement of 4-6m 3 The impact of / min on yield, such as Figure 7 As shown in the figure. Simulation results indicate that changing the displacement has a limited effect on the post-compression effect, that is, the impact on output is minimal. This is because the displacement increases from 4m³ / h. 3 / min increased to 6m 3 When the fracturing rate is 1 / min, the change in the fracture area is not significant.

[0063] Furthermore, to determine the impact of proppant addition on fracturing efficiency in each segment, two cases with low and high fracture development were used as examples, with proppant addition amounts of 50, 75, and 100 m³ per segment. 3 The impact of post-fracturing on production is compared, as shown in Table 3. Simulation results show that, compared with the impact of changing the displacement on the post-fracturing effect, changing the proppant dosage for each segment has a limited impact on production, i.e., the impact on production is very small. This is because although increasing the proppant dosage will appropriately increase the fracturing scale, the increase is mainly in the dynamic fracture length, and the increase in effective fracture length is limited (>100 md.m). However, when comparing different fracture development levels, the decrease in proppant dosage has a slightly larger impact on reservoirs with low fracture development. This is because the hydraulic fractures are not completely connected to the natural fractures, and the natural fractures have a limited effect on improving production. Similarly, when increasing the total proppant dosage, from 300 m 3 Increase to 500m 3 At that time, the corresponding number of fracturing stages increased to 5, 10, and 15 stages. It can be seen that increasing the number of fracture stages and the proppant dosage can increase the production of horizontal well fracturing, such as... Figure 8 As shown. However, the increase is limited, especially for high-density naturally fractured reservoirs.

[0064] Table 3. Effect of different proppant addition amounts on fracturing performance in each segment.

[0065]

[0066] The above examples can help determine the optimal fracturing parameters to provide a preferred staged fracturing scheme for horizontal wells in fractured reservoirs, thereby improving the effectiveness of horizontal well stimulation.

[0067] Accordingly, this invention constructs a hydraulic fracturing model for a pre-defined reservoir region; embeds the fracture network formed by hydraulic fracturing in the hydraulic fracturing model into a dynamic flow model of the oil and gas reservoir using an unstructured mesh, thus obtaining a numerical simulation model of the reservoir; and simulates the development of the entire horizontal well section by setting fracture development parameters and fracturing parameters for the target horizontal well, determining the optimal fracturing parameters by predicting production within a pre-defined time period. This forms an integrated geological engineering method for fractured reservoirs based on a geological model, simulating fracturing in the entire horizontal well section. Based on this method, this invention can determine a segmented fracturing construction scheme for horizontal wells in fractured reservoirs, improving the effectiveness of horizontal well stimulation.

[0068] Furthermore, in this embodiment of the invention, a reservoir geological model is established based on data such as structural layers, lithofacies, and faults. Combined with well logging and coherence data, the geological model is endowed with reservoir properties, in-situ stress, and natural fracture distribution characteristics. Based on this geological model, a reservoir hydraulic fracturing model is established. The established geological and hydraulic fracturing models are calibrated using construction parameters, pump shutdown pressure, and construction curves from multiple fractured horizontal wells. Microseismic fracture monitoring data is used to correct the distribution of natural fractures, the magnitude of in-situ stress, and the difference coefficient, ensuring that the established geological engineering model conforms to the actual conditions of the target block. The hydraulic fracturing model can simulate the interaction between the main fracture and natural fractures, complex hydraulic fracture morphology, stress interference between multiple fractures, and proppant migration within fractures. The resulting fracture parameters are embedded into an unstructured grid-based dynamic flow model of the oil and gas reservoir, resulting in a reservoir numerical simulation model used to calculate the corresponding production rate. To improve the accuracy of reservoir numerical simulation models, local mesh refinement is applied to hydraulic and natural fractures around the fractured horizontal well. Actual production data from previous fractured wells are used for fitting, and the reservoir simulation model parameters are corrected to suit practical application conditions. For example, the reduced fracture conductivity caused by proppant embedding and breakage is considered. By setting discrete natural fracture networks of high, medium, and low densities in the target reservoir, hydraulic fracturing simulation is conducted across the entire horizontal well section. Post-fracturing annual production is predicted under a constant bottomhole flow pressure constraint for N years (e.g., N=5), thereby determining the optimal fracturing parameters (e.g., number of fracturing stages, fracturing stage length, fracturing fluid volume, proppant dosage, displacement, fracture spacing, etc.). This forms an integrated geological engineering method for fracturing fractured reservoirs based on geological models, simulating fracturing across the entire horizontal well section. Based on this method, embodiments of the present invention can determine segmented fracturing construction schemes for horizontal wells in fractured reservoirs, improving the horizontal well stimulation effect. Embodiments of the present invention have significant guiding significance for improving the horizontal well fracturing effect of unconventional resources such as shale oil and gas and tight gas with fracture development.

[0069] This invention also provides a control device, which includes a memory, a processor, and a computer program stored in the memory and executable on the processor. The processor executes the computer program to implement the above-described fracturing optimization method for all horizontal well sections.

[0070] This invention also provides a machine-readable storage medium storing instructions that cause a machine to execute the aforementioned fracturing optimization method for all horizontal well sections.

[0071] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0072] This application is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of this application. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart... Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0073] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0074] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1The steps of the function specified in one or more boxes.

[0075] In a typical configuration, a computing device includes one or more processors (CPU), input / output interfaces, network interfaces, and memory.

[0076] Memory may include non-persistent memory in computer-readable media, such as random access memory (RAM) and / or non-volatile memory, such as read-only memory (ROM) or flash RAM. Memory is an example of computer-readable media.

[0077] Computer-readable media includes both permanent and non-permanent, removable and non-removable media that can store information using any method or technology. Information can be computer-readable instructions, data structures, modules of programs, or other data. Examples of computer storage media include, but are not limited to, phase-change memory (PRAM), static random access memory (SRAM), dynamic random access memory (DRAM), other types of random access memory (RAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), flash memory or other memory technologies, CD-ROM, digital versatile optical disc (DVD) or other optical storage, magnetic tape, magnetic magnetic disk storage or other magnetic storage devices, or any other non-transferable medium that can be used to store information accessible by a computing device. As defined herein, computer-readable media does not include transient computer-readable media, such as modulated data signals and carrier waves.

[0078] It should also be noted that the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such process, method, article, or apparatus. Unless otherwise specified, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes that element.

[0079] The above are merely embodiments of this application and are not intended to limit the scope of this application. Various modifications and variations can be made to this application by those skilled in the art. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of this application should be included within the scope of the claims of this application.

Claims

1. A fracturing optimization method for all horizontal well sections, characterized in that, The fracturing optimization method for all horizontal well sections includes: Based on the geological data, well logging data and coherence data of the preset area, a hydraulic fracturing model of the reservoir in the preset area is constructed. The fracture network formed by hydraulic fracturing in the hydraulic fracturing model is embedded into the dynamic flow model of the oil and gas reservoir using an unstructured mesh, resulting in a numerical simulation model of the reservoir; and By setting the fracture development parameters and fracturing parameters for the target horizontal well, the development simulation of the entire horizontal well section of the reservoir is carried out using the numerical simulation model. The optimal fracturing parameters are determined by predicting the production rate within a preset time.

2. The fracturing optimization method for all horizontal well sections according to claim 1, characterized in that, The step of constructing a hydraulic fracturing model for the reservoir in the preset area based on geological data, well logging data, and coherence data includes: Based on the geological data, a geological model is constructed, wherein the geological data includes structural bedding planes, lithofacies, and fault data of the preset area; Using the well logging data and the coherence data, reservoir properties, geostress, and natural fracture distribution characteristics are embedded into the geological model; and Based on the geological model with embedded features, the hydraulic fracturing model is constructed to simulate the interaction between the main fracture and natural fractures, complex hydraulic fracture morphology, stress interference between multiple fractures, and proppant migration within the fractures.

3. The fracturing optimization method for all horizontal well sections according to claim 2, characterized in that, After constructing the hydraulic fracturing model, the fracturing optimization method for the entire horizontal well section further includes: Acquire construction data, including construction parameters, pump shutdown pressure, and construction curves of the horizontal well after fracturing in the preset area; and Based on the construction data, the geological model and the hydraulic fracturing model are revised.

4. The fracturing optimization method for all horizontal well sections according to claim 1, characterized in that, After obtaining the reservoir numerical simulation model, the fracturing optimization method for the entire horizontal well section further includes: Based on the reservoir numerical simulation model, the hydraulic fractures and natural fractures are locally meshed around the fractured horizontal well; and The reservoir numerical simulation model is fitted using the actual production data of the fractured horizontal well to correct the reservoir numerical simulation model.

5. The fracturing optimization method for all horizontal well sections according to claim 1, characterized in that, After obtaining the reservoir numerical simulation model, the fracturing optimization method for the entire horizontal well section further includes: Sensitivity analysis of fracturing parameters was performed on the reservoir numerical simulation model to determine the fracturing parameters and their corresponding design parameters. The fracturing parameters include the number of fracturing stages and the corresponding length of each fracturing stage.

6. The fracturing optimization method for all horizontal well sections according to claim 5, characterized in that, The fracturing parameters also include one or more of the following: natural fracture density, fracture spacing, fracturing fluid volume proppant dosage, displacement, and total proppant dosage.

7. The fracturing optimization method for all horizontal well sections according to claim 1, characterized in that, The process involves setting parameters for fracture development and fracturing in the target horizontal well, and then performing a full-horizontal well section development simulation on the reservoir numerical simulation model. This includes: Based on the constant bottom-hole flow pressure condition, discrete natural fracture networks corresponding to different fracture development parameters are embedded into the reservoir numerical simulation model; and For the different fracture development parameters, different fracturing parameters are embedded into the reservoir numerical simulation model to simulate the development of the entire horizontal well section and predict the production within the corresponding preset time period.

8. The fracturing optimization method for all horizontal well sections according to claim 7, characterized in that, The method of determining the optimal fracturing parameters by predicting the production output within a preset time period includes: Grouping those with the same fracture development degree parameter into a single group, and comparing the production increase within the preset time period after performing full-horizontal well section development simulations under different fracturing parameters, the results are as follows. The fracturing parameters corresponding to the highest increase in production within the preset time period are the optimal fracturing parameters under the given fracture development level parameter.

9. A control device, characterized in that, The control device includes: a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the fracturing optimization method for all horizontal well sections according to any one of claims 1-8.

10. A machine-readable storage medium, characterized in that, The machine-readable storage medium stores instructions that cause the machine to perform the fracturing optimization method for all horizontal well sections according to any one of claims 1-8.

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