A directional hydraulic fracturing method and device based on ground stress regulation structure, electronic equipment and storage medium

Abstract

This invention discloses a method, apparatus, electronic device, and storage medium for directional hydraulic fracturing based on a geostress-controlled structure. The method includes: acquiring geological parameters of the target reservoir and in-situ fracturing fracture monitoring data; designing a geostress-controlled structure based on the azimuth information of the target oil and gas reservoir and its geological conditions; constructing a reservoir-scale numerical model of the target reservoir based on the geostress-controlled structure and geological parameters; performing hydraulic fracturing simulation on the reservoir-scale numerical model and determining the degree of fracture direction deflection based on the simulation results; optimizing the target parameters of the reservoir-scale numerical model in a stratified manner with the goal of minimizing the degree of fracture direction deflection, and obtaining the optimal combination of process parameters after optimization; and determining the construction scheme for the target reservoir based on the optimal combination of process parameters. This scheme can achieve directional hydraulic fracturing of the target reservoir and actively guide the directional propagation of hydraulically fracturing fractures.

Description

Technical Field

[0001] This invention relates to the field of oil and gas reservoir stimulation technology, and in particular to a directional hydraulic fracturing method, apparatus, electronic equipment and storage medium based on a geostress control structure. Background Technology

[0002] Hydraulic fracturing is a commonly used technique for enhancing oil and gas reservoir production. However, conventional hydraulic fracturing fractures mainly propagate unidirectionally along the direction of maximum principal stress. When the oil and gas reservoir is located in a direction other than the direction of maximum principal stress, conventional fractures are difficult to effectively communicate, resulting in low reservoir utilization.

[0003] To address this issue, existing technologies typically divide the wellbore perimeter into different zones based on the distance and azimuth between the reservoir and the wellbore, employing different fracturing strategies. This often relies on temporary plugging agents for deflection and high-energy pulse waves, but such methods still struggle to achieve directional deflection of fractures over large distances and angles, and the ability to control fracture propagation direction is limited when using only a single process. Summary of the Invention

[0004] This invention provides a directional hydraulic fracturing method, apparatus, electronic device, and storage medium based on a geostress control structure. It can actively change the local geostress field around the well through the geostress control structure, and induce hydraulic fracturing fractures to initiate and propagate in a predetermined direction, thereby realizing directional hydraulic fracturing of the target reservoir.

[0005] In a first aspect, the present invention provides a directional hydraulic fracturing method based on a geostress-regulating structure, comprising: Acquire geological parameters of the target reservoir and on-site fracturing fracture monitoring data; Based on the azimuth information of the target oil and gas reservoir and the geological conditions of the target reservoir, a geostress control structure is designed; wherein the geostress control structure consists of at least one of the following structures: radial well, directional perforation hole, and temporary plugging diversion hole; Based on the aforementioned geostress regulation structure and geological parameters, a reservoir-scale numerical model of the target reservoir is constructed. Hydraulic fracturing simulation under actual working conditions was performed on the reservoir-scale numerical model. The degree of fracture direction deflection was determined based on the hydraulic fracturing simulation results, and the degree of fracture direction deflection was used as an evaluation index for fracture directional propagation. With the goal of minimizing the degree of fracture direction deflection, the target parameters of the reservoir-scale numerical model are optimized in layers, and the optimal combination of process parameters is obtained after optimization; wherein, the target parameters include control structure parameters and construction parameters; Based on the optimal combination of process parameters, a construction scheme for the target reservoir is determined to perform directional hydraulic fracturing on the target reservoir.

[0006] Secondly, the present invention also provides a directional hydraulic fracturing device based on a geostress regulation structure, comprising: The data acquisition module is used to acquire geological parameters of the target reservoir and on-site fracturing fracture monitoring data; The geostress control structure design module is used to design a geostress control structure based on the azimuth information of the target oil and gas reservoir and the geological conditions of the target reservoir; wherein the geostress control structure consists of at least one of the following structures: radial well, directional perforation hole, and temporary plugging diversion hole; The reservoir-scale numerical model construction module is used to construct a reservoir-scale numerical model of the target reservoir based on the geostress regulation structure and the geological parameters. The fracture direction deflection degree determination module is used to perform hydraulic fracturing simulation under actual working conditions on the reservoir-scale numerical model, determine the fracture direction deflection degree based on the hydraulic fracturing simulation results, and use the fracture direction deflection degree as an evaluation index for fracture directional propagation. The parameter optimization module is used to perform hierarchical optimization of the target parameters of the reservoir-scale numerical model with the goal of minimizing the degree of fracture direction deflection, and to obtain the optimal combination of process parameters after optimization; wherein, the target parameters include control structure parameters and construction parameters; The construction scheme determination module is used to determine the construction scheme of the target reservoir based on the optimal combination of process parameters, so as to carry out directional hydraulic fracturing of the target reservoir.

[0007] Thirdly, this invention also provides an electronic device, comprising: One or more processors; Storage device for storing one or more programs. When the one or more programs are executed by the one or more processors, the one or more processors implement the directional hydraulic fracturing method based on geostress-controlled structures as provided in any embodiment of the present invention.

[0008] Fourthly, the present invention also provides a storage medium containing computer-executable instructions, which, when executed by a computer processor, are used to perform the directional hydraulic fracturing method based on a geostress-regulating structure as provided in any embodiment of the present invention.

[0009] The technical solution of this invention involves acquiring geological parameters of the target reservoir and on-site fracturing fracture monitoring data; designing a geostress control structure based on the azimuth information and geological conditions of the target oil and gas reservoir; thereby enabling the subsequent use of the geostress control structure to actively change the local geostress field around the well, inducing hydraulic fracturing fractures to initiate and propagate in a predetermined direction, forming a main fracture channel connecting the target oil and gas reservoir; wherein the geostress control structure consists of at least one of the following structures: a radial well, a directional perforation orifice, and a temporary plugging diversion hole; constructing a reservoir-scale numerical model of the target reservoir based on the geostress control structure and geological parameters; and performing hydraulic fracturing simulation under actual operating conditions on the reservoir-scale numerical model. Based on hydraulic fracturing simulation results, the degree of fracture direction deflection is determined and used as an evaluation index for directional fracture propagation, thus providing a quantitative evaluation index determination method and a clear quantitative basis for subsequent parameter optimization. With the goal of minimizing fracture direction deflection, the target parameters of the reservoir-scale numerical model are optimized hierarchically, resulting in the optimal combination of process parameters. These target parameters include control structure parameters and construction parameters, achieving hierarchical optimization of multiple target parameters and determining the process parameter combination with the best directional hydraulic fracturing effect. Based on the optimal process parameter combination, a construction scheme for the target reservoir is determined for directional hydraulic fracturing. This scheme can actively change the local geostress field around the well through a geostress control structure, inducing hydraulic fracturing fractures to propagate in a predetermined direction. This overcomes the limitation of traditional fractures only propagating along the direction of maximum principal stress, enabling directional hydraulic fracturing of the target reservoir, actively guiding the directional propagation of hydraulic fracturing fractures, and quantitatively evaluating its guiding effect.

[0010] The above description of the invention is merely an overview of the technical solution of the present invention. In order to better understand the technical means of the present invention and to implement it in accordance with the contents of the specification, and to make the above and other objects, features and advantages of the present invention more apparent and understandable, specific embodiments of the present invention are described below. Attached Figure Description

[0011] The above and other features, advantages, and aspects of the various embodiments of the present invention will become more apparent from the accompanying drawings and the following detailed description. Throughout the drawings, the same or similar reference numerals denote the same or similar elements. It should be understood that the drawings are schematic, and the originals and elements are not necessarily drawn to scale.

[0012] Figure 1 This is a schematic flowchart of a directional hydraulic fracturing method based on a geostress-regulating structure provided in an embodiment of the present invention; Figure 2 This is a schematic diagram illustrating the effect of a physical-scale numerical model provided in an embodiment of the present invention; Figure 3 A diagram illustrating the calculation principle of crack direction deflection provided in an embodiment of the present invention; Figure 4 This is a schematic flowchart of another directional hydraulic fracturing method based on a geostress-regulating structure provided in an embodiment of the present invention; Figure 5 This is a simulation result diagram of crack propagation morphology under different azimuth angles provided in an embodiment of the present invention; Figure 6 This is a schematic diagram of a directional hydraulic fracturing device based on a geostress control structure provided in an embodiment of the present invention; Figure 7 This is a schematic diagram of an electronic device for a directional hydraulic fracturing method for realizing a geostress-controlled structure, as provided in an embodiment of the present invention. Detailed Implementation

[0013] Embodiments of the present invention will now be described in more detail with reference to the accompanying drawings. While some embodiments of the invention are shown in the drawings, it should be understood that the invention can be implemented in various forms and should not be construed as limited to the embodiments set forth herein. Rather, these embodiments are provided to provide a more thorough and complete understanding of the invention. It should be understood that the accompanying drawings and embodiments are for illustrative purposes only and are not intended to limit the scope of protection of the invention.

[0014] It should be understood that the various steps described in the method embodiments of the present invention may be performed in different orders and / or in parallel. Furthermore, the method embodiments may include additional steps and / or omit the steps shown. The scope of the present invention is not limited in this respect.

[0015] The term "comprising" and its variations as used herein are open-ended inclusions, meaning "including but not limited to". The term "based on" means "at least partially based on". The term "one embodiment" means "at least one embodiment"; the term "another embodiment" means "at least one additional embodiment"; the term "some embodiments" means "at least some embodiments". Definitions of other terms will be given in the description below.

[0016] It should be noted that the concepts of "first" and "second" mentioned in this invention are only used to distinguish different devices, modules or units, and are not used to limit the order of functions performed by these devices, modules or units or their interdependencies.

[0017] It should be noted that the terms "a" and "a plurality of" used in this invention are illustrative rather than restrictive. Those skilled in the art should understand that, unless otherwise expressly indicated in the context, they should be understood as "one or more".

[0018] The names of the messages or information exchanged between the multiple devices in the embodiments of the present invention are for illustrative purposes only and are not intended to limit the scope of these messages or information.

[0019] Figure 1 This is a schematic flowchart of a directional hydraulic fracturing method based on a geostress-controlled structure provided in an embodiment of the present invention. This embodiment is applicable to directional hydraulic fracturing of reservoirs containing oil and gas, enabling the fracturing fractures generated in the reservoir to propagate in a directional manner. This method can be executed by a directional hydraulic fracturing device based on a geostress-controlled structure. This device can be implemented in software and / or hardware and is generally integrated into any electronic device with network communication capabilities, such as a mobile terminal, PC, or server. Figure 1 As shown, the directional hydraulic fracturing method based on geostress-controlled structures in this embodiment of the invention may include the following processes: S110. Obtain geological parameters of the target reservoir and on-site fracturing fracture monitoring data.

[0020] Among them, the target reservoir refers to the reservoir that needs to be subjected to directional hydraulic fracturing, and the target reservoir may contain oil and gas reservoirs / collections that need to be exploited.

[0021] Accordingly, geological parameters refer to parameters that reflect the geological conditions of the target reservoir. In this embodiment, geological parameters include at least one of the following: triaxial geostress of the target reservoir, rock elastic modulus, Poisson's ratio, tensile strength, permeability, porosity, etc. Field fracturing fracture monitoring data refers to the data related to fracturing fractures monitored after the initial fracturing of the target reservoir. For example, field fracturing fracture monitoring data can indicate various information such as the main propagation direction and angle of the fracturing fractures generated during the initial fracturing.

[0022] Specifically, geological parameters of the target reservoir and on-site fracturing monitoring data can be obtained through preliminary exploration and on-site construction data. For example, the geological parameters of the target reservoir may be as follows: vertical stress 42 MPa, maximum horizontal principal stress 40 MPa, minimum horizontal principal stress 37 MPa, original pore pressure 20 MPa, rock elastic modulus 13.9 GPa, Poisson's ratio 0.25, tensile strength 3 MPa, and permeability of [missing information]. The porosity is 0.1. Field fracturing fracture monitoring data indicates that when conventional fracturing technology is used to perform early fracturing on the target reservoir well or adjacent well, the resulting fracturing fractures mainly extend along the direction of maximum principal stress (NE75°), while the target oil and gas reservoir to be developed is located in the NE45° direction, with an angle of 30° with the direction of maximum principal stress.

[0023] S120. Based on the azimuth information of the target oil and gas reservoir and the geological information of the target reservoir, design the geostress control structure; wherein, the geostress control structure consists of at least one of the following structures: radial well, directional perforation orifice, and temporary plugging diversion hole.

[0024] The geostress control structure can be understood as a control structure that can actively change the local geostress field around the target reservoir well. This geostress control structure can induce hydraulic fracturing fractures to initiate and propagate in a predetermined direction. In this embodiment, the geostress control structure can consist of at least one of the following structures: a radial well, a directional perforation orifice, and a temporary plugging diversion hole.

[0025] Specifically, a geostress control structure can be designed based on the azimuth information of the target oil and gas reservoir and the geological conditions of the target reservoir. This geostress control structure can be used to alter the local geostress field of the target reservoir. The designed geostress control structure can be obtained from one or more combinations of radial wells, directional perforations, and temporarily plugged diversion holes. Of course, other different structures can also be used to design the geostress control structure based on actual needs, construction conditions, cost, and other factors. After the geostress control structure design is completed, various parameters such as the azimuth angle, effective length, and equivalent diameter of the geostress control structure can be determined.

[0026] For example, the azimuth information of the target oil and gas reservoir / target reservoir is that it is located at an angle of 30° with the direction of the maximum principal stress. After considering the geological information of the target reservoir, the in-situ stress control structure can be initially designed as a radial well with an azimuth angle of 30°, an effective length of 15m, and an equivalent diameter of 30mm.

[0027] S130. Based on the geostress regulation structure and geological parameters, a reservoir-scale numerical model of the target reservoir is constructed.

[0028] The reservoir-scale numerical model can be understood as not only quantifying the designed geostress regulation structure, but also considering the geological parameters of the target reservoir during the model construction process. This reservoir-scale numerical model can be used for parameter optimization in subsequent schemes.

[0029] It should be noted that, in this embodiment, although the designed geostress control structure is a physical structure (to be used subsequently for directional hydraulic fracturing of the target reservoir), given the potential need to adjust relevant parameters within the geostress control structure or to further optimize these parameters based on the actual formation characteristics of the target reservoir, a corresponding numerical model can be constructed for the geostress control structure. The geological parameters of the target reservoir are considered during the model construction process to match the actual characteristics and requirements of the target reservoir, thereby obtaining a reservoir-scale numerical model of the target reservoir. Obtaining such a reservoir-scale numerical model facilitates iterative optimization of various relevant parameters within the numerical model in subsequent schemes.

[0030] As an optional but non-limiting implementation, a reservoir-scale numerical model of the target reservoir is constructed based on the geostress control structure and geological parameters. This includes: obtaining physical test results of the geostress control structure; wherein the physical test results indicate the parameter information of the hydraulic fracturing fractures formed after the geostress control structure undergoes a physical hydraulic fracturing process; constructing a physical-scale numerical model based on the test parameters of the geostress control structure and the physical hydraulic fracturing process, and simulating the hydraulic fracturing process using the extended finite element method to obtain the model simulation results; and, provided that the similarity between the model simulation results and the physical test results meets the preset similarity requirements, constructing a reservoir-scale numerical model based on the physical-scale numerical model and geological parameters. Using this optional scheme, the constructed physical-scale numerical model can be used to verify the technological feasibility of the geostress control structure, overcoming the size limitations of physical test simulations, and constructing a reservoir-scale numerical model that fits the actual geological characteristics of the target reservoir based on the physical-scale numerical model and geological parameters.

[0031] Physical hydraulic fracturing refers to the use of high-pressure fluids to hydraulically fracture test samples, simulating the physical and mechanical processes of crack generation and propagation in rocks. The specific experimental procedures for physical hydraulic fracturing can be customized based on actual needs. For example, in this embodiment, the physical hydraulic fracturing process may include at least true triaxial fracturing and acid injection.

[0032] Correspondingly, the physical test results are used to indicate the parameter information of the hydraulic fracturing fractures formed after the physical hydraulic fracturing process by the stress-regulating structure. The parameter information of these hydraulic fracturing fractures includes at least: the fracture initiation location, the propagation trajectory, and the final fracture morphology. It should be noted that this embodiment, by performing a physical hydraulic fracturing process on the stress-regulating structure and recording the parameter information of the resulting hydraulic fracturing fractures, facilitates subsequent assessments of the stress-regulating structure's control capabilities. This allows for determination of whether the stress-regulating structure can induce directional propagation of the generated hydraulic fracturing fractures, thereby enabling a feasibility assessment of the process.

[0033] Specifically, the physical test results of the geostress control structure can be obtained first. These results indicate the parameter information of the hydraulic fracturing fractures formed after the geostress control structure undergoes a physical hydraulic fracturing process. Then, a physical-scale numerical model can be constructed based on the test parameters of the geostress control structure and the physical hydraulic fracturing process. This physical-scale numerical model can be understood as a numerical model directly corresponding to the geostress control structure, used to replicate the geostress control structure and verify the feasibility of the process. Further, the extended finite element method can be used to simulate the hydraulic fracturing process using this physical-scale numerical model, and the simulation results are obtained after the simulation process is completed. It can be understood that the physical test results are obtained after conducting actual physical hydraulic fracturing tests on the geostress control structure, while the physical-scale numerical model is the numerical model corresponding to the geostress control structure, and the simulation results are obtained after simulating the hydraulic fracturing process in the same way. Therefore, the simulation results and the physical test results can be compared to determine whether the currently constructed physical-scale numerical model is consistent with the geostress control structure, thus verifying the feasibility of the process. If the similarity between the model simulation results and the physical test results meets the preset similarity requirements, it indicates that the physical-scale numerical model can maintain consistency with the geostress regulation structure, and the process is feasible and reliable. The physical-scale numerical model has initially acquired the ability to enable the directional propagation of hydraulic fracturing fractures. Therefore, based on the physical-scale numerical model and geological parameters, a reservoir-scale numerical model can be constructed.

[0034] Of course, if the similarity between the model simulation results and the physical experiment results does not meet the preset similarity requirements, the parameters of the physical-scale numerical model can be continuously adjusted until the similarity between the model simulation results and the physical experiment results meets the preset similarity requirements. These preset similarity requirements can be set differently based on actual needs, and will not be detailed here.

[0035] As an optional but non-limiting implementation method, the physical test results are determined as follows: The geostress control structure is placed in a reservoir rock simulation sample; the reservoir rock simulation sample is placed in a true triaxial fracturing system, and the triaxial stress of the reservoir rock simulation sample is loaded to a preset stress value and maintained for a preset duration to simulate the pre-fracturing process; after the pre-fracturing process is simulated, acid is injected into the reservoir rock simulation sample according to preset acid configuration information to simulate the acid dissolution process; after the acid dissolution process is completed, the physical test results are determined based on the parameter information of the hydraulic fracturing fractures formed in the reservoir rock simulation sample. Using this optional scheme, the physical test results can be determined based on the detailed information of the hydraulic fracturing fractures actually formed after fracturing by actually operating the geostress control structure during the physical hydraulic fracturing process.

[0036] The preset acid configuration information includes at least the concentration, flow rate, and injection time of the injected acid.

[0037] Specifically, when performing physical hydraulic fracturing on a stress-regulating structure, the stress-regulating structure can first be placed in a reservoir rock simulation sample, preferably a rock sample identical or similar to the target reservoir. Then, the reservoir rock simulation sample can be placed in a true triaxial fracturing system, and the triaxial stress of the reservoir rock simulation sample can be loaded to a preset stress value and maintained for a preset duration to simulate the pre-fracturing process. Next, after the pre-fracturing process is simulated, acid can be injected into the reservoir rock simulation sample according to preset acid configuration information to simulate the acid dissolution process. By simulating the pre-fracturing and acid dissolution processes, the physical hydraulic fracturing simulation of the stress-regulating structure can be completed. After the acid dissolution process is completed, the hydraulic fracturing fractures formed in the reservoir rock simulation sample can be analyzed to determine the parameter information of the hydraulic fracturing fractures formed in the reservoir rock simulation sample, and further physical test results can be determined based on these parameter information.

[0038] For example, the following provides a complete illustrative explanation of the process of constructing a reservoir-scale numerical model of a target reservoir based on geostress-controlled structures and geological parameters: (1) Assuming the designed geostress control structure is a radial well with an azimuth angle of 30°, its effective length is initially set at 15m, and its equivalent diameter is initially set at 30mm. The radial well can be implemented using a welded steel pipe with an outer diameter of 12mm, a length of 80mm, and holes on all four sides. Then, according to the similarity criterion, a carbonate rock simulation sample with a size of 300mm×300mm×300mm can be prepared, and its carbonate rock content is greater than 90% (same as or similar to the rock sample composition of the target reservoir). A simulated radial well (i.e., geostress control structure) can be pre-placed in the carbonate rock simulation sample, and the sample can be placed in a true triaxial fracturing system and loaded with triaxial stress to the simulated design value (vertical stress 20MPa, maximum horizontal principal stress 15MPa, minimum horizontal principal stress 12MPa). During the simulation process, water with added dilute red ink as a tracer is injected at a flow rate of 10mL / min for 10 minutes to simulate the hydraulic fracturing process / pre-fracturing process. After reaching the preset time, the injection concentration of hydrochloric acid (4.41 mol / L with added dark red ink as a tracer) is switched and continuously injected at a rate of 6 mL / min for 10 minutes to simulate the subsequent acid dissolution process (including acidification to expand the channel and the unblocking process). After the entire experiment, the sample can be dissected to determine parameters such as the initiation location, propagation trajectory, and final morphology of the hydraulic fracturing fractures, and then physical test results can be obtained based on these parameters. For example, the physical test results may indicate that the hydraulic fracturing fractures initiate at the bottom of the simulated radial well, initially propagate approximately 65 mm along the radial direction, then gradually deviate towards the direction of maximum principal stress, eventually forming a hydraulic fracturing fracture deviating from the predetermined direction.

[0039] (2) A physical-scale numerical model is constructed using experimental parameters of the geostress-controlled structure and the physical hydraulic fracturing process. For example, a physical-scale numerical model can be established in the finite element simulation software ABAQUS. Figure 2 This is a schematic diagram illustrating the effect of a physical-scale numerical model provided in an embodiment of the present invention, such as... Figure 2 As shown, the physical-scale numerical model has dimensions of 300mm × 300mm × 300mm, with the rock elastic modulus set to 12.46 GPa, Poisson's ratio to 0.17, and tensile strength to 2.6 MPa. Then, the Soil module is used to simulate fluid-structure interaction, and the Extended Finite Element Model (XFEM) is used to simulate random fracture propagation. The maximum principal stress criterion is used to determine fracture initiation, and the Black-Kruger law is used as the propagation criterion, thus simulating the hydraulic fracturing process. Furthermore, when it is necessary to evaluate the acidizing effect, acid injection can be switched after the hydraulic fracturing simulation is completed to simulate the acid dissolution process (including acidizing to expand channels and unblocking processes). The model simulation results are obtained after the overall simulation process is completed.

[0040] (3) After obtaining the model simulation results, the model simulation results and physical test results can be compared. The comparison shows that the fracture initiation location, propagation trajectory and deflection morphology of the two are highly consistent. This indicates that the similarity between the model simulation results and the physical test results meets the preset similarity requirements, verifying that the established physical-scale numerical model is technologically feasible. Then, based on the physical-scale numerical model and geological parameters, a reservoir-scale numerical model can be constructed. For example, the calculated domain diameter of the constructed reservoir-scale numerical model is 40m, with a vertical wellbore with a diameter of 139.7mm at the center. Extending outward from the wellbore is a stress control structure simulating a radial well. The stress control structure has an azimuth angle of 30°, a length of 15m, and a diameter of 30mm. The simulation construction parameters of the reservoir-scale numerical model are: pre-flush fluid discharge rate. Injection time: 10 minutes; acid discharge rate The injection time was 40 minutes, and the acid concentration was 4.41 mol / L.

[0041] S140. Perform hydraulic fracturing simulation on the reservoir-scale numerical model under actual working conditions. Determine the degree of fracture direction deflection based on the hydraulic fracturing simulation results, and use the degree of fracture direction deflection as an evaluation index for fracture directional propagation.

[0042] Understandably, while it is expected that hydraulic fracturing fractures will generate and propagate in a predetermined direction, the actual hydraulic fracturing process is influenced by various factors, and the resulting hydraulic fracturing fractures may deviate. For example, a fracture may initially initiate and propagate approximately 14.2 m along the radial well direction (NE45°), and then gradually deviate towards the direction of maximum principal stress (NE75°). To address this, this embodiment introduces the degree of fracture direction deviance as an evaluation index for fracture directional propagation.

[0043] The degree of fracture direction deflection can be understood as a parameter used to assess the straightness of hydraulic fracturing fracture propagation along a predetermined direction. Specifically, it reflects the degree of directional deflection between the actual hydraulic fracturing fracture and the expected propagating hydraulic fracturing fracture. The method for constructing / determining this degree of fracture direction deflection can be customized based on actual needs.

[0044] Specifically, after constructing the reservoir-scale numerical model, hydraulic fracturing simulations under actual operating conditions can be performed. Based on the simulation results, the degree of fracture direction deflection can be determined, and this degree of deflection is used as an evaluation index for directional fracture propagation. This parameter can assess whether the actual hydraulically generated fractures propagate straight along the desired direction, thus facilitating the evaluation of the directional hydraulic fracturing capability of the current reservoir-scale numerical model. The smaller the value of the fracture direction deflection, the better the fracture propagation along the predetermined direction.

[0045] As an optional but non-limiting implementation, the degree of fracture direction deflection is determined based on hydraulic fracturing simulation results. This includes: determining the formed hydraulic fracturing fracture based on the simulation results; determining the first area enclosed by the hydraulic fracturing fracture, the axis of the geostress control structure, and the boundary of the guide circle; wherein the guide circle is a circle with the center of the geostress control structure as its center and the distance between the formed hydraulic fracturing fracture and the center of the circle as its radius; and determining the degree of fracture direction deflection based on the ratio between the first area and the area of ​​the guide circle. This optional scheme can determine the degree of fracture direction deflection using the guide circle and the first area, thus providing a quantitative evaluation index determination method and offering a clear quantitative basis for subsequent parameter optimization.

[0046] The guide circle can be understood as a circle constructed in this embodiment to determine the degree of fracture direction deflection, used to assist in parameter calculations during intermediate processes. Specifically, the guide circle is formed with the center of the "ground stress regulation structure" as its center and the "distance between the formed hydraulic fracturing fracture and the center of the circle" as its radius.

[0047] Specifically, the formed hydraulic fracturing fractures can be determined based on the results of hydraulic fracturing simulations. Then, the first area enclosed by the hydraulic fracturing fractures, the axis of the geostress control structure, and the boundary of the guide circle is determined. Next, the degree of fracture direction deflection can be determined based on the ratio between the first area and the area of ​​the guide circle. For example, Figure 3 This is an explanatory diagram illustrating the calculation principle of crack direction deflection provided in an embodiment of the present invention, as shown below. Figure 3 As shown, the red dashed line represents the guide circle, which is a circle drawn with the vertical wellbore (which is the center of the geostress control structure) as its center and the distance between the tip of the fracture and the center of the circle (i.e., the distance between the formed hydraulic fracturing fracture and the center of the circle) as its radius. Figure 3 In the diagram, the area enclosed by the fracture (corresponding to a hydraulic fracturing fracture), the radial well (corresponding to the axis of the geostress control structure), and the guide circle is the first area (i.e., Figure 3The irregular blue area in the image can be used to calculate the degree of crack direction deflection using the following formula: ; Where D represents the degree of deflection of the crack direction; D represents the first area; S represents the area of ​​the guiding circle. The smaller the D value, the better the crack propagates in the predetermined direction.

[0048] S150. With the goal of minimizing the degree of fracture direction deflection, the target parameters of the reservoir-scale numerical model are optimized in layers, and the optimal combination of process parameters is obtained after optimization. Among them, the target parameters include control structure parameters and construction parameters.

[0049] Here, target parameters refer to the parameters that need to be optimized. There can be multiple target parameters; in this embodiment, target parameters include control structure parameters and construction parameters. Control structure parameters refer to the relevant structural parameters of the geostress control structure in the reservoir-scale numerical model, while construction parameters refer to the parameters used during directional hydraulic-pressure operations on the reservoir-scale numerical model. Optionally, in this embodiment, control structure parameters include at least: the azimuth angle of the geostress control structure, the effective length of the geostress control structure, and the diameter of the geostress control structure; construction parameters include at least: pre-flush fluid discharge rate, acid concentration, and acid discharge rate. Of course, these parameter types can be expanded and enriched based on actual needs; they are not limited in detail here.

[0050] Specifically, after determining the degree of fracture direction deflection, this degree can be used as an evaluation index for directional fracture propagation. The target parameters of the reservoir-scale numerical model are then optimized hierarchically, with the goal of minimizing the degree of fracture direction deflection. The optimal combination of process parameters is then obtained. This optimal combination contains several different parameters, enabling the entire reservoir-scale numerical model to achieve directional propagation of hydraulically fractured fractures, with the overall directional propagation effect being optimal.

[0051] S160. Determine the construction scheme for the target reservoir based on the optimal combination of process parameters, so as to carry out directional hydraulic fracturing of the target reservoir.

[0052] Specifically, after obtaining the optimal combination of process parameters, a construction plan for the target reservoir can be determined based on the optimal combination of process parameters. This construction plan can be directly used to guide the on-site fracturing construction design, so as to carry out directional hydraulic fracturing of the target reservoir, so that the generated hydraulic fracturing fractures can propagate in the desired direction.

[0053] The technical solution of this invention involves acquiring geological parameters of the target reservoir and on-site fracturing fracture monitoring data; designing a geostress control structure based on the azimuth information and geological conditions of the target oil and gas reservoir; thereby enabling the subsequent use of the geostress control structure to actively change the local geostress field around the well, inducing hydraulic fracturing fractures to initiate and propagate in a predetermined direction, forming a main fracture channel connecting the target oil and gas reservoir; wherein the geostress control structure consists of at least one of the following structures: a radial well, a directional perforation orifice, and a temporary plugging diversion hole; constructing a reservoir-scale numerical model of the target reservoir based on the geostress control structure and geological parameters; and performing hydraulic fracturing simulation under actual operating conditions on the reservoir-scale numerical model. Based on hydraulic fracturing simulation results, the degree of fracture direction deflection is determined and used as an evaluation index for directional fracture propagation, thus providing a quantitative evaluation index determination method and a clear quantitative basis for subsequent parameter optimization. With the goal of minimizing fracture direction deflection, the target parameters of the reservoir-scale numerical model are optimized hierarchically, resulting in the optimal combination of process parameters. These target parameters include control structure parameters and construction parameters, achieving hierarchical optimization of multiple target parameters and determining the process parameter combination with the best directional hydraulic fracturing effect. Based on the optimal process parameter combination, a construction scheme for the target reservoir is determined for directional hydraulic fracturing. This scheme can actively change the local geostress field around the well through a geostress control structure, inducing hydraulic fracturing fractures to propagate in a predetermined direction. This overcomes the limitation of traditional fractures only propagating along the direction of maximum principal stress, enabling directional hydraulic fracturing of the target reservoir, actively guiding the directional propagation of hydraulic fracturing fractures, and quantitatively evaluating its guiding effect.

[0054] Figure 4 This is a schematic flowchart of another directional hydraulic fracturing method based on geostress-controlled structures provided by an embodiment of the present invention. The technical solution of this embodiment, based on the technical solutions of the above embodiments, further optimizes the process of performing layered optimization of the target parameters of the reservoir-scale numerical model with the goal of minimizing fracture direction deflection, and obtaining the optimal combination of process parameters after optimization. This embodiment can be combined with various optional solutions in one or more of the above embodiments. Figure 4 As shown, the directional hydraulic fracturing method based on geostress-controlled structures in this embodiment of the invention may include the following processes: S410. Obtain geological parameters of the target reservoir and on-site fracturing fracture monitoring data.

[0055] S420. Based on the azimuth information of the target oil and gas reservoir and the geological information of the target reservoir, design a geostress control structure; wherein, the geostress control structure consists of at least one of the following structures: radial well, directional perforation orifice, and temporary plugging diversion hole.

[0056] S430. Based on the geostress regulation structure and geological parameters, a reservoir-scale numerical model of the target reservoir is constructed.

[0057] S440. Perform hydraulic fracturing simulation on the reservoir-scale numerical model under actual working conditions. Determine the degree of fracture direction deflection based on the hydraulic fracturing simulation results, and use the degree of fracture direction deflection as an evaluation index for fracture directional propagation.

[0058] S450. Determine the azimuth angle of the geostress regulation structure in the reservoir-scale numerical model, and determine whether the azimuth angle meets the preset azimuth angle constraint conditions.

[0059] The azimuth angle of the geostress control structure refers to the angle between the direction of the geostress control structure and the direction of the maximum horizontal principal stress. Preset azimuth angle constraints indicate the allowable deviation range between the azimuth angle of the geostress control structure and the azimuth information of the target oil and gas reservoir. These preset azimuth angle constraints can be customized based on actual needs. For example, a preset azimuth angle constraint could be: the azimuth deviation angle between the azimuth angle of the geostress control structure and the actual azimuth of the target oil and gas reservoir cannot exceed 15°.

[0060] Specifically, the azimuth angle of the geostress regulation structure in the reservoir-scale numerical model can be determined, and the azimuth deviation angle (which has both direction and angle magnitude) between this azimuth angle and the actual azimuth of the target oil and gas reservoir can be determined. The actual azimuth of the target oil and gas reservoir can be determined based on its azimuth information. After determining the azimuth deviation angle, it can be judged whether the current azimuth angle of the geostress regulation structure meets the preset azimuth constraint conditions.

[0061] Understandably, using preset azimuth constraints to determine the azimuth of the stress regulation structure can screen and ascertain whether the current azimuth is feasible. For example, if the azimuth meets the preset azimuth constraints, it means that the stress regulation structure can ensure that the subsequent fracture propagation direction covers the target oil and gas reservoir, and therefore the azimuth is feasible. Conversely, if the azimuth does not meet the preset azimuth constraints, it means that the target oil and gas reservoir cannot be covered at that azimuth, and therefore the azimuth is infeasible, meaning the scheme lacks engineering feasibility and can be excluded. Therefore, this embodiment uses the feasibility assessment of the azimuth of the stress regulation structure to perform the first level of parameter optimization for the reservoir-scale numerical model.

[0062] For example, Figure 5 This is a simulation result diagram of crack propagation morphology under different azimuth angles provided in an embodiment of the present invention, as shown in the figure. Figure 5As shown, with other conditions remaining unchanged, simulations were conducted by setting the azimuth angles of the geostress control structure to 15°, 30°, 45°, 60°, and 90° respectively. Specifically: the control structure corresponding to the 15° azimuth angle points to NE60°, which deviates by 15° from the target oil and gas reservoir's location at NE45°, and therefore cannot effectively cover the target area, so it was excluded; while the 30° azimuth angle points to NE45°, which can accurately cover the direction of the target reservoir; azimuth angles of 45° and above deviate further from the target direction and are also not feasible.

[0063] S460. Under the condition that the azimuth angle meets the preset azimuth angle constraint, the construction parameters of the reservoir-scale numerical model are fixed, the control structure parameters are optimized, and the combination of control structure parameters is obtained after optimization.

[0064] Specifically, when the azimuth angle meets the preset azimuth constraint conditions, the construction parameters of the reservoir-scale numerical model can be fixed. For example, these construction parameters can be fixed to the conventional design values ​​used during on-site construction. Then, the control structure parameters are optimized. For example, multiple sets of values ​​can be constructed for simulation by changing the values ​​of each control structure parameter, and selection can be performed based on the simulation effect of each set of values ​​(e.g., calculating the fracture direction deflection degree D corresponding to each scheme and then selecting). This optimizes the control structure parameters in the reservoir-scale numerical model. After optimization, a combination of control structure parameters is obtained, which consists of the optimized control structure parameters. For example, it can be a combination of parameters consisting of the azimuth angle, effective length, and diameter of the geostress control structure. Therefore, this embodiment achieves a second level of parameter optimization for the reservoir-scale numerical model by fixing the construction parameters and optimizing the control structure parameters.

[0065] For example, the pre-fluid discharge rate, acid concentration, and acid discharge rate can be fixed to the conventional design values ​​on site. Under the premise that the azimuth angle is determined, only the effective length and equivalent diameter of the stress control structure are changed to obtain multiple sets of values. Multiple sets of numerical simulations are then performed to calculate the degree of crack direction deflection D corresponding to each scheme. With the goal of minimizing the D value, the optimal combination of length and diameter is selected to obtain the combination of control structure parameters.

[0066] S470. Based on the combination of control structure parameters, the control structure parameters of the reservoir-scale numerical model are fixed, the construction parameters are optimized, and the combination of construction parameters is obtained after optimization.

[0067] Specifically, after optimizing the control structure parameters, the control structure parameters of the reservoir-scale numerical model can be fixed based on the obtained combination of control structure parameters. This can be achieved by setting each control parameter according to the values ​​in the control structure parameter combination, and further optimizing the construction parameters. The principle of the optimization process can still be to determine multiple sets of values ​​and perform simulations, then filter based on the degree of fracture direction deflection D corresponding to each set of values, etc. The detailed principle is the same as above and will not be elaborated here. After optimization, the construction parameter combination can be obtained. This construction parameter combination consists of the optimized construction parameters, for example, it can be a parameter combination consisting of pre-fluid discharge rate, acid concentration, and acid discharge rate. Therefore, this embodiment achieves third-level parameter optimization of the reservoir-scale numerical model by fixing the control structure parameters and optimizing the construction parameters.

[0068] For example, based on the obtained combination of control structure parameters, each control structure parameter (azimuth, length, diameter) can be fixed, and multiple sets of numerical simulations can be performed by only changing the pre-fluid discharge rate, acid concentration, and acid discharge rate. The optimal combination of construction parameters can be selected with the goal of minimizing the crack direction deflection degree D value corresponding to each set.

[0069] As an optional but non-limiting implementation, the control structure parameters of the reservoir-scale numerical model are fixed, and the construction parameters are optimized. This includes: fixing the control structure parameters of the reservoir-scale numerical model and determining multiple construction parameters to be optimized; using grey relational analysis to calculate the grey relational coefficients between each construction parameter and the degree of fracture direction deflection; determining the influence weight of each construction parameter based on its corresponding grey relational coefficient; and optimizing each construction parameter sequentially according to its influence weight from largest to smallest during the optimization process. Using this optional approach, the grey relational coefficients between each construction parameter and the degree of fracture direction deflection can be calculated, and the influence weight of each construction parameter can be determined based on the grey relational coefficients, thereby determining the order in which the construction parameters are optimized, thus reducing the blindness and cost of the optimization process.

[0070] The grey relational coefficient can be used to characterize the degree of correlation between construction parameters and the degree of crack direction deflection. The larger the grey relational coefficient, the higher the degree of correlation and the closer the relationship between construction parameters and the degree of crack direction deflection; the smaller the grey relational coefficient, the weaker the correlation between construction parameters and the degree of crack direction deflection.

[0071] Specifically, the control structure parameters of the reservoir-scale numerical model can be fixed to determine multiple construction parameters to be optimized. Then, grey relational analysis is used to calculate the grey relational coefficients between each construction parameter and the degree of fracture direction deflection. Next, based on the grey relational coefficients corresponding to each construction parameter, the influence weight of each construction parameter is determined; for example, if the grey relational coefficient of a certain construction parameter is higher, a larger influence weight can be assigned to that construction parameter. Then, in the process of optimizing the construction parameters, each construction parameter can be optimized sequentially according to the order of influence weight from largest to smallest.

[0072] For example, when fixing the control structure parameters of the reservoir-scale numerical model and optimizing the construction parameters, grey relational analysis can be used to calculate the grey relational coefficients between each construction parameter and the degree of fracture direction deflection D. The results are as follows: the grey relational coefficient corresponding to the pre-flush fluid discharge rate is 0.9011, the grey relational coefficient corresponding to the acid concentration is 0.9008, and the grey relational coefficient corresponding to the acid discharge rate is 0.9001. Then, according to the grey relational coefficients corresponding to each construction parameter, the corresponding influence weights can be assigned to each construction parameter. The influence weights of each construction parameter from largest to smallest can be: pre-flush fluid discharge rate > acid concentration > acid discharge rate. In a more detailed optimization process, the pre-flush fluid discharge rate can be adjusted from... Optimized to Simulation results showed that the crack direction deflection D decreased from 0.021 to 0.015, while the crack propagation distance along the predetermined direction increased from 14.2m to 16.8m. Based on this optimization sequence, the acid concentration and acid discharge rate can be further optimized sequentially to obtain a better combination of construction parameters.

[0073] S480. Based on the combination of control structural parameters and construction parameters, determine the optimal combination of process parameters.

[0074] Specifically, after the target parameters of the reservoir-scale numerical model are optimized in layers, the optimal combination of process parameters can be determined based on the combination of control structure parameters and construction parameters. For example, the optimal combination of process parameters determined after optimization could be: stress control structure (radial well) azimuth angle 30°, length 15m, diameter 30mm, fracturing fluid discharge rate... Using the scheme corresponding to these process parameters, the hydraulic fracturing fractures are expected to effectively extend 16.8m along the predetermined direction (NE45°), effectively covering the target oil and gas reservoir. The fracture direction deflection is only 0.015, demonstrating a significant directional fracture propagation effect. If necessary, acid can be subsequently injected for acidizing to further expand the fracture channel and remove near-wellbore contamination.

[0075] S490. Determine the construction scheme for the target reservoir based on the optimal combination of process parameters, so as to carry out directional hydraulic fracturing of the target reservoir.

[0076] Specifically, the construction scheme for the target reservoir can be determined based on the optimal combination of process parameters. Alternatively, the effective stimulation volume of the target reservoir can be considered during the determination process, and the stimulation effect of each scheme can be comprehensively evaluated. The combination of process parameters with the smallest fracture direction deflection and the largest effective stimulation volume can be selected to determine the construction scheme for the target reservoir. This construction scheme can be directly used to guide the on-site fracturing construction design for directional hydraulic fracturing of the target reservoir.

[0077] Alternatively, besides using a radial well design, the stress control structure can also be designed using a temporarily plugged directional hole design. During the corresponding physical hydraulic fracturing test, two symmetrical temporarily plugged holes (10mm diameter, 50mm depth, 30° azimuth) can be pre-installed on the vertical wellbore wall to simulate a directional hole. A plugging agent is added simultaneously with the pre-fracturing fluid injection, forcing the fracture to initiate in the predetermined direction. Reservoir-scale model simulation results show that the temporarily plugged directional hole can also guide fracture directional propagation, with a fracture direction deflection D of 0.035 under the same conditions. Although its guiding effect is slightly weaker than that of a radial well of the same size, this type of stress control structure offers greater flexibility and lower cost, while still achieving targeted stimulation effects away from the direction of maximum principal stress. Other design options for stress control structures can be flexibly selected based on site conditions and cost.

[0078] The technical solution of this invention involves acquiring geological parameters of the target reservoir and on-site fracturing fracture monitoring data; designing a geostress control structure based on the azimuth information and geological conditions of the target oil and gas reservoir; thereby enabling the subsequent use of the geostress control structure to actively change the local geostress field around the well, inducing hydraulic fracturing fractures to initiate and propagate in a predetermined direction, forming a main fracture channel connecting the target oil and gas reservoir; wherein the geostress control structure consists of at least one of the following structures: a radial well, a directional perforation orifice, and a temporary plugging deflection orifice; constructing a reservoir-scale numerical model of the target reservoir based on the geostress control structure and geological parameters; performing hydraulic fracturing simulation under actual operating conditions on the reservoir-scale numerical model; determining the degree of fracture direction deflection based on the hydraulic fracturing simulation results; and using the degree of fracture direction deflection as an evaluation index for directional fracture propagation, thus providing a quantitative method for determining the evaluation index. This process provides a clear quantitative basis for parameter optimization in subsequent schemes; it determines the azimuth angle of the geostress control structure in the reservoir-scale numerical model and judges whether the azimuth angle meets the preset azimuth angle constraint conditions; if the azimuth angle meets the preset azimuth angle constraint conditions, the construction parameters of the reservoir-scale numerical model are fixed, the control structure parameters are optimized, and the combination of control structure parameters is obtained after optimization; based on the combination of control structure parameters, the control structure parameters of the reservoir-scale numerical model are fixed, the construction parameters are optimized, and the combination of construction parameters is obtained after optimization; based on the combination of control structure parameters and the combination of construction parameters, the optimal combination of process parameters is determined, thereby realizing the hierarchical optimization of multiple target parameters and determining the combination of process parameters with the best directional hydraulic fracturing effect; based on the optimal combination of process parameters, the construction scheme of the target reservoir is determined to carry out directional hydraulic fracturing of the target reservoir. This scheme can actively change the local geostress field around the well through the geostress control structure, which can induce hydraulic fracturing fractures to initiate and propagate in a predetermined direction. This breaks through the limitation of traditional fractures that only propagate in the direction of maximum principal stress, and can realize directional hydraulic fracturing of target reservoirs, actively guide the directional propagation of hydraulic fracturing fractures, and at the same time, quantitatively evaluate its guiding effect.

[0079] Figure 6 This is a schematic diagram of a directional hydraulic fracturing device based on a geostress-controlled structure, provided in an embodiment of the present invention. This embodiment is applicable to directional hydraulic fracturing of reservoirs containing oil and gas, enabling the fracturing fractures generated in the reservoir to propagate in a directional manner. This geostress-controlled directional hydraulic fracturing device can be implemented in software and / or hardware, and is generally integrated into any electronic device with network communication capabilities, such as a mobile terminal, PC, or server. Figure 6As shown, the directional hydraulic fracturing device with a geostress control structure according to an embodiment of the present invention may include a data acquisition module 610, a geostress control structure design module 620, a reservoir-scale numerical model construction module 630, a fracture direction deflection determination module 640, a parameter optimization module 650, and a construction scheme determination module 660. Wherein: Data acquisition module 610 is used to acquire geological parameters of the target reservoir and on-site fracturing fracture monitoring data; The geostress control structure design module 620 is used to design a geostress control structure based on the azimuth information of the target oil and gas reservoir and the geological information of the target reservoir; wherein the geostress control structure is composed of at least one of the following structures: radial well, directional perforation hole and temporary plugging diversion hole; The reservoir-scale numerical model construction module 630 is used to construct a reservoir-scale numerical model of the target reservoir based on the geostress regulation structure and the geological parameters. The fracture direction deflection degree determination module 640 is used to perform hydraulic fracturing simulation under actual working conditions on the reservoir-scale numerical model, determine the fracture direction deflection degree based on the hydraulic fracturing simulation results, and use the fracture direction deflection degree as an evaluation index for fracture directional propagation. The parameter optimization module 650 is used to perform hierarchical optimization of the target parameters of the reservoir-scale numerical model with the goal of minimizing the degree of fracture direction deflection, and to obtain the optimal combination of process parameters after optimization; wherein, the target parameters include control structure parameters and construction parameters; The construction scheme determination module 660 is used to determine the construction scheme of the target reservoir based on the optimal combination of process parameters, so as to carry out directional hydraulic fracturing of the target reservoir.

[0080] The technical solution of this invention involves acquiring geological parameters of the target reservoir and on-site fracturing fracture monitoring data through a data acquisition module; designing a geostress control structure based on the azimuth information and geological conditions of the target oil and gas reservoir through a geostress control structure design module, thereby enabling the active alteration of the local geostress field around the well using the geostress control structure to induce hydraulic fracturing fractures to initiate and propagate in a predetermined direction, forming a main fracture channel connecting the target oil and gas reservoir; wherein the geostress control structure comprises at least one of the following structures: a radial well, a directional perforation orifice, and a temporary plugging deflection orifice; constructing a reservoir-scale numerical model of the target reservoir based on the geostress control structure and geological parameters through a reservoir-scale numerical model construction module; and determining the degree of fracture deflection through a fracture direction determination module. Hydraulic fracturing simulation under actual operating conditions is used to determine the degree of fracture direction deflection based on the simulation results. This degree of deflection is then used as an evaluation index for directional fracture propagation, providing a quantitative method for determining the evaluation index and offering a clear quantitative basis for subsequent parameter optimization. The parameter optimization module optimizes the target parameters of the reservoir-scale numerical model in a stratified manner, aiming to minimize the degree of fracture direction deflection. The optimal combination of process parameters is obtained after optimization. The target parameters include control structure parameters and construction parameters, thus achieving stratified optimization of multiple target parameters and determining the process parameter combination with the best directional hydraulic fracturing effect. The construction scheme determination module determines the construction scheme for the target reservoir based on the optimal combination of process parameters, enabling directional hydraulic fracturing of the target reservoir. This scheme can actively change the local geostress field around the well through the geostress control structure, inducing directional fracturing fractures to initiate and propagate in a predetermined direction. This overcomes the limitation of traditional fractures only propagating along the direction of maximum principal stress, enabling directional hydraulic fracturing of the target reservoir and actively guiding the directional propagation of hydraulic fracturing fractures. It also allows for quantitative evaluation of the guiding effect.

[0081] As an optional but non-limiting implementation, the reservoir-scale numerical model construction module 630 includes a physical experiment result acquisition unit, a model simulation result determination unit, and a reservoir-scale numerical model construction unit. Wherein: The physical test result acquisition unit is used to acquire the physical test results of the geostress control structure; wherein, the physical test results are used to indicate the parameter information of the hydraulic fracturing fractures formed by the geostress control structure after undergoing the physical hydraulic fracturing process; The model simulation result determination unit is used to construct a physical-scale numerical model based on the experimental parameters of the geostress control structure and the physical hydraulic fracturing process, and to simulate the hydraulic fracturing process of the physical-scale numerical model using the extended finite element method to obtain the model simulation results. The reservoir-scale numerical model construction unit is used to construct the reservoir-scale numerical model based on the physical-scale numerical model and the geological parameters, provided that the similarity between the model simulation results and the physical test results meets the preset similarity requirements.

[0082] As an optional but non-limiting implementation, the physical test results are determined as follows: the geostress control structure is placed in a reservoir rock simulation sample; the reservoir rock simulation sample is placed in a true triaxial fracturing system, and the triaxial stress of the reservoir rock simulation sample is loaded to a preset stress value and maintained for a preset duration to simulate the pre-fracturing process; after the pre-fracturing process is simulated, acid is injected into the reservoir rock simulation sample according to preset acid configuration information to simulate the acid dissolution process; after the acid dissolution process is completed, the physical test results are determined based on the parameter information of the hydraulic fracturing fractures formed in the reservoir rock simulation sample.

[0083] As an optional but non-limiting implementation, the fracture direction deflection degree determination module 640 includes a hydraulic fracturing fracture determination unit, a first area determination unit, and a fracture direction deflection degree determination unit. Wherein: A hydraulic fracturing fracture determination unit is used to determine the formed hydraulic fracturing fractures based on the hydraulic fracturing simulation results. The first area determination unit is used to determine the first area enclosed by the hydraulic fracturing fracture, the axis of the geostress control structure, and the boundary of the guide circle; wherein the guide circle is a circle formed with the center of the geostress control structure as the center and the distance between the formed hydraulic fracturing fracture and the center of the circle as the radius; The crack direction deflection degree determination unit is used to determine the crack direction deflection degree based on the ratio between the first area and the area of ​​the guide circle.

[0084] As an optional but non-limiting implementation, the control structure parameters include at least: the azimuth angle of the stress control structure, the effective length of the stress control structure, and the diameter of the stress control structure; the construction parameters include at least: the pre-fluid discharge rate, the acid concentration, and the acid discharge rate.

[0085] As an optional but non-limiting implementation, the parameter optimization module 650 includes an azimuth angle determination unit, a structural parameter optimization unit, a construction parameter optimization unit, and an optimal process parameter combination determination unit. Wherein: The azimuth angle determination unit is used to determine the azimuth angle of the geostress control structure in the reservoir-scale numerical model and to determine whether the azimuth angle meets the preset azimuth angle constraint conditions. The regulating structure parameter optimization unit is used to fix the construction parameters of the reservoir-scale numerical model, optimize the regulating structure parameters, and obtain the regulating structure parameter combination after the optimization is completed, provided that the azimuth angle meets the preset azimuth angle constraint conditions. The construction parameter optimization unit is used to fix the control structure parameters of the reservoir-scale numerical model based on the control structure parameter combination, optimize the construction parameters, and obtain the construction parameter combination after optimization. The optimal process parameter combination determination unit is used to determine the optimal process parameter combination based on the control structure parameter combination and the construction parameter combination.

[0086] As an optional but non-limiting implementation, the construction parameter optimization unit includes a sub-unit for determining the parameters to be optimized, a sub-unit for determining the grey relational coefficient, a sub-unit for determining the influence weight, and a sub-unit for optimizing the construction parameters. Wherein: The sub-unit for determining parameters to be optimized is used to fix the control structure parameters of the reservoir-scale numerical model and determine multiple construction parameters to be optimized in the reservoir-scale numerical model. The grey relational coefficient determination sub-unit is used to calculate the grey relational coefficient between each of the construction parameters and the degree of crack direction deflection using the grey relational analysis method. The influence weight determination subunit is used to determine the influence weight of each construction parameter based on the gray relational coefficients corresponding to each construction parameter. The construction parameter optimization subunit is used to optimize each construction parameter in descending order of influence weight during the optimization process.

[0087] The directional hydraulic fracturing device with a geostress-regulating structure provided in this embodiment of the invention can be used to perform the directional hydraulic fracturing method with a geostress-regulating structure, and has the corresponding functional modules and beneficial effects for performing the directional hydraulic fracturing method with a geostress-regulating structure.

[0088] It is worth noting that the various units and modules included in the above-mentioned device are only divided according to functional logic, but are not limited to the above division, as long as the corresponding functions can be realized; in addition, the specific names of each functional unit are only for easy differentiation and are not used to limit the protection scope of the embodiments of the present invention.

[0089] Figure 7 This is a schematic diagram of an electronic device for a directional hydraulic fracturing method for realizing a geostress-controlled structure, provided in an embodiment of the present invention. The following refers to... Figure 7The diagram illustrates a structural schematic of an electronic device 710 suitable for implementing embodiments of the present invention. The terminal devices in these embodiments may include, but are not limited to, mobile terminals such as mobile phones, laptops, digital broadcast receivers, PDAs (personal digital assistants), PADs (tablet computers), PMPs (portable multimedia players), in-vehicle terminals (e.g., in-vehicle navigation terminals), and fixed terminals such as digital TVs and desktop computers. Figure 7 The electronic device shown is merely an example and should not be construed as limiting the functionality and scope of use of the embodiments of the present invention.

[0090] like Figure 7 As shown, the electronic device 710 includes at least one processor 711 and a memory, such as a read-only memory (ROM) 712 and a random access memory (RAM) 713, communicatively connected to the at least one processor 711. The memory stores computer programs executable by the at least one processor. The processor 711 can perform various appropriate actions and processes based on the computer program stored in the ROM 712 or loaded from storage unit 718 into the RAM 713. The RAM 713 may also store various programs and data required for the operation of the electronic device 710. The processor 711, ROM 712, and RAM 713 are interconnected via a bus 714. An input / output (I / O) interface 715 is also connected to the bus 714.

[0091] Multiple components in electronic device 710 are connected to input / output (I / O) interface 715, including: input unit 716, such as keyboard, mouse, etc.; output unit 717, such as various types of monitors, speakers, etc.; storage unit 718, such as disk, optical disk, etc.; and communication unit 719, such as network card, modem, wireless transceiver, etc. Communication unit 719 allows electronic device 710 to exchange information / data with other devices through computer networks such as the Internet and / or various telecommunications networks.

[0092] Processor 711 can be a variety of general-purpose and / or special-purpose processing components with processing and computing capabilities. Some examples of processor 711 include, but are not limited to, central processing unit (CPU), graphics processing unit (GPU), various special-purpose artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, digital signal processors (DSPs), and any suitable processor, controller, microcontroller, etc. Processor 711 executes the directional hydraulic fracturing method for in-situ stress regulation structures provided in any embodiment of the present invention.

[0093] In particular, according to embodiments of the present invention, the processes described above with reference to the flowchart can be implemented as computer software programs. For example, embodiments of the present invention include a computer program product comprising a computer program carried on a non-transitory computer-readable medium, the computer program containing program code for performing a directional hydraulic fracturing method for a stress-controlled structure as shown in the flowchart. In such embodiments, the computer program can be downloaded and installed from a network via a communication unit 719, or installed from a storage unit 718, or installed from a read-only memory (ROM) 712. When the computer program is executed by a processor 711, it performs the functions defined in the directional hydraulic fracturing method for a stress-controlled structure according to embodiments of the present invention.

[0094] The names of the messages or information exchanged between the multiple devices in the embodiments of the present invention are for illustrative purposes only and are not intended to limit the scope of these messages or information.

[0095] The electronic device provided in this embodiment of the invention and the directional hydraulic fracturing method with geostress control structure provided in the above embodiment belong to the same inventive concept. Technical details not described in detail in this embodiment can be found in the above embodiment, and this embodiment has the same beneficial effects as the above embodiment.

[0096] This invention provides a computer storage medium storing a computer program that, when executed by a processor, implements the directional hydraulic fracturing method for the geostress control structure provided in the above embodiments.

[0097] It should be noted that the computer-readable medium described above in this invention can be a computer-readable signal medium, a computer-readable storage medium, or any combination thereof. A computer-readable storage medium can be, for example,—but not limited to—an electrical, magnetic, optical, electromagnetic, infrared, or semiconductor system, apparatus, or device, or any combination thereof. More specific examples of a computer-readable storage medium may include, but are not limited to: an electrical connection having one or more wires, a portable computer disk, a hard disk, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), optical fiber, portable compact disk read-only memory (CD-ROM), optical storage device, magnetic storage device, or any suitable combination thereof. In this invention, a computer-readable storage medium can be any tangible medium containing or storing a program that can be used by or in conjunction with an instruction execution system, apparatus, or device. In this invention, a computer-readable signal medium can include a data signal propagated in baseband or as part of a carrier wave, carrying computer-readable program code. Such propagated data signals can take various forms, including but not limited to electromagnetic signals, optical signals, or any suitable combination thereof. A computer-readable signal medium can be any computer-readable medium other than a computer-readable storage medium, which can send, propagate, or transmit a program for use by or in connection with an instruction execution system, apparatus, or device. The program code contained on the computer-readable medium can be transmitted using any suitable medium, including but not limited to: wires, optical fibers, RF (radio frequency), etc., or any suitable combination thereof.

[0098] Computer program code for performing the operations of this invention can be written in one or more programming languages ​​or a combination thereof, including but not limited to object-oriented programming languages ​​such as Java, Smalltalk, and C++, as well as conventional procedural programming languages ​​such as "C" or similar programming languages. The program code can be executed entirely on the user's computer, partially on the user's computer, as a standalone software package, partially on the user's computer and partially on a remote computer, or entirely on a remote computer or server. In cases involving remote computers, the remote computer can be connected to the user's computer via any type of network—including a local area network (LAN) or a wide area network (WAN)—or can be connected to an external computer (e.g., via the Internet using an Internet service provider).

[0099] The flowcharts and block diagrams in the accompanying drawings illustrate the architecture, functionality, and operation of possible implementations of systems, methods, and computer program products according to various embodiments of the present invention. In this regard, each block in a flowchart or block diagram may represent a module, segment, or portion of code containing one or more executable instructions for implementing a specified logical function. It should also be noted that in some alternative implementations, the functions indicated in the blocks may occur in a different order than those indicated in the drawings. For example, two consecutively indicated blocks may actually be executed substantially in parallel, and they may sometimes be executed in reverse order, depending on the functions involved. It should also be noted that each block in the block diagrams and / or flowcharts, and combinations of blocks in the block diagrams and / or flowcharts, can be implemented using a dedicated hardware-based system that performs the specified function or operation, or using a combination of dedicated hardware and computer instructions.

[0100] The units described in the embodiments of the present invention can be implemented in software or in hardware. The names of the units are not, in some cases, intended to limit the specific unit.

[0101] The functions described above in this document can be performed at least in part by one or more hardware logic components. For example, exemplary types of hardware logic components that can be used, without limitation, include: field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), application-specific standard products (ASSPs), system-on-a-chip (SoCs), complex programmable logic devices (CPLDs), and so on.

[0102] In the context of this invention, a machine-readable medium can be a tangible medium that may contain or store a program for use by or in conjunction with an instruction execution system, apparatus, or device. A machine-readable medium can be a machine-readable signal medium or a machine-readable storage medium. Machine-readable media can include, but are not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, apparatus, or devices, or any suitable combination of the foregoing. More specific examples of machine-readable storage media include electrical connections based on one or more wires, portable computer disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), optical fibers, portable compact disk read-only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination of the foregoing.

[0103] The above description is merely a preferred embodiment of the present invention and an explanation of the technical principles employed. Those skilled in the art should understand that the scope of disclosure in this invention is not limited to technical solutions formed by specific combinations of the above-described technical features, but should also cover other technical solutions formed by arbitrary combinations of the above-described technical features or their equivalents without departing from the above-disclosed concept. For example, technical solutions formed by substituting the above features with (but not limited to) technical features with similar functions disclosed in this invention.

[0104] Furthermore, while the operations are described in a specific order, this should not be construed as requiring these operations to be performed in the specific order shown or in sequential order. Multitasking and parallel processing may be advantageous in certain environments. Similarly, while several specific implementation details are included in the above discussion, these should not be construed as limiting the scope of the invention. Certain features described in the context of individual embodiments may also be implemented in combination in a single embodiment. Conversely, various features described in the context of a single embodiment may also be implemented individually or in any suitable sub-combination in multiple embodiments.

[0105] Although the subject matter has been described using language specific to structural features and / or methodological logic, it should be understood that the subject matter defined in the appended claims is not necessarily limited to the specific features or actions described above. Rather, the specific features and actions described above are merely illustrative examples of implementing the claims.

Claims

1. A directional hydraulic fracturing method based on a geostress-regulating structure, characterized in that, The method includes: Acquire geological parameters of the target reservoir and on-site fracturing fracture monitoring data; Based on the azimuth information of the target oil and gas reservoir and the geological conditions of the target reservoir, a geostress control structure is designed; wherein the geostress control structure consists of at least one of the following structures: radial well, directional perforation hole, and temporary plugging diversion hole; Based on the aforementioned geostress regulation structure and geological parameters, a reservoir-scale numerical model of the target reservoir is constructed. Hydraulic fracturing simulation under actual working conditions was performed on the reservoir-scale numerical model. The degree of fracture direction deflection was determined based on the hydraulic fracturing simulation results, and the degree of fracture direction deflection was used as an evaluation index for fracture directional propagation. With the goal of minimizing the degree of fracture direction deflection, the target parameters of the reservoir-scale numerical model are optimized in layers, and the optimal combination of process parameters is obtained after optimization; wherein, the target parameters include control structure parameters and construction parameters; Based on the optimal combination of process parameters, a construction scheme for the target reservoir is determined to perform directional hydraulic fracturing on the target reservoir.

2. The method according to claim 1, characterized in that, Based on the aforementioned geostress regulation structure and geological parameters, a reservoir-scale numerical model of the target reservoir is constructed, including: Obtain the physical test results of the geostress control structure; wherein, the physical test results are used to indicate the parameter information of the hydraulic fracturing fractures formed by the geostress control structure after undergoing the physical hydraulic fracturing process; A physical-scale numerical model was constructed based on the experimental parameters of the aforementioned geostress control structure and the physical hydraulic fracturing process. The extended finite element method was then used to simulate the hydraulic fracturing process using the physical-scale numerical model, and the simulation results were obtained. If the similarity between the model simulation results and the physical test results meets the preset similarity requirements, the reservoir-scale numerical model is constructed based on the physical-scale numerical model and the geological parameters.

3. The method according to claim 2, characterized in that, The results of the physical tests were determined in the following manner: The aforementioned geostress regulation structure was placed in a reservoir rock simulation sample; The reservoir rock simulation sample is placed in a true triaxial fracturing system, and the triaxial stress of the reservoir rock simulation sample is applied to a preset stress value and continued for a preset duration to simulate the pre-fracturing process. After the pre-flushing process is simulated, acid is injected into the reservoir rock simulation sample according to the preset acid configuration information to simulate the acid dissolution process. After the acid dissolution process is completed, the physical test results are determined based on the parameter information of the hydraulic fracturing fractures formed in the reservoir rock simulation sample.

4. The method according to claim 1, characterized in that, The degree of fracture orientation deflection is determined based on the results of hydraulic fracturing simulation, including: Based on the hydraulic fracturing simulation results, the formed hydraulic fracturing fractures are determined; A first area is defined by the axis of the hydraulic fracturing fracture, the geostress control structure, and the boundary of the guide circle; wherein the guide circle is a circle with the center of the geostress control structure as its center and the distance between the formed hydraulic fracturing fracture and the center of the circle as its radius; The degree of crack direction deflection is determined based on the ratio between the first area and the area of ​​the guide circle.

5. The method according to claim 1, characterized in that, The parameters of the control structure include at least: the azimuth angle of the stress control structure, the effective length of the stress control structure, and the diameter of the stress control structure; the construction parameters include at least: the pre-fluid discharge rate, the acid concentration, and the acid discharge rate.

6. The method according to claim 1, characterized in that, The target parameters of the reservoir-scale numerical model are optimized hierarchically, and the optimal combination of process parameters is obtained after optimization, including: Determine the azimuth angle of the geostress regulation structure in the reservoir-scale numerical model, and determine whether the azimuth angle meets the preset azimuth angle constraint conditions; When the azimuth angle meets the preset azimuth angle constraint conditions, the construction parameters of the reservoir-scale numerical model are fixed, the control structure parameters are optimized, and the control structure parameter combination is obtained after optimization. Based on the combination of control structure parameters, the control structure parameters of the reservoir-scale numerical model are fixed, the construction parameters are optimized, and the combination of construction parameters is obtained after optimization. Based on the combination of control structure parameters and the combination of construction parameters, the optimal combination of process parameters is determined.

7. The method according to claim 6, characterized in that, The control structure parameters of the reservoir-scale numerical model are fixed, and the construction parameters are optimized, including: The control structure parameters of the reservoir-scale numerical model are fixed, and multiple construction parameters to be optimized in the reservoir-scale numerical model are determined. Grey relational analysis was used to calculate the grey relational coefficients between each of the construction parameters and the degree of crack direction deflection. Based on the grey relational coefficients corresponding to each of the construction parameters, the influence weights corresponding to each of the construction parameters are determined. In the process of optimizing the construction parameters, each construction parameter is optimized in turn according to the order of influence weight from large to small.

8. A directional hydraulic fracturing device based on a geostress regulation structure, characterized in that, The device includes: The data acquisition module is used to acquire geological parameters of the target reservoir and on-site fracturing fracture monitoring data; The geostress control structure design module is used to design a geostress control structure based on the azimuth information of the target oil and gas reservoir and the geological conditions of the target reservoir; wherein the geostress control structure consists of at least one of the following structures: radial well, directional perforation hole, and temporary plugging diversion hole; The reservoir-scale numerical model construction module is used to construct a reservoir-scale numerical model of the target reservoir based on the geostress regulation structure and the geological parameters. The fracture direction deflection degree determination module is used to perform hydraulic fracturing simulation under actual working conditions on the reservoir-scale numerical model, determine the fracture direction deflection degree based on the hydraulic fracturing simulation results, and use the fracture direction deflection degree as an evaluation index for fracture directional propagation. The parameter optimization module is used to perform hierarchical optimization of the target parameters of the reservoir-scale numerical model with the goal of minimizing the degree of fracture direction deflection, and to obtain the optimal combination of process parameters after optimization; wherein, the target parameters include control structure parameters and construction parameters; The construction scheme determination module is used to determine the construction scheme of the target reservoir based on the optimal combination of process parameters, so as to carry out directional hydraulic fracturing of the target reservoir.

9. An electronic device, characterized in that, The electronic device includes: One or more processors; Storage device for storing one or more programs. When the one or more programs are executed by the one or more processors, the one or more processors implement the directional hydraulic fracturing method based on geostress-controlled structures as described in any one of claims 1-7.

10. A storage medium containing computer-executable instructions, characterized in that, The computer-executable instructions, when executed by a computer processor, are used to perform the directional hydraulic fracturing method based on a geostress-controlled structure as described in any one of claims 1-7.

Images