Method, device and medium for improving recovery ratio of horizontal well volume fracturing development

Abstract

The invention discloses a recovery efficiency improving method and device for horizontal well volume fracturing development and a medium. The method comprises the steps that S10, basic parameters of a target oil reservoir are obtained; s20, determining a volume fracturing and seam spacing driving and mining development mode; s30, parameter optimization of the inter-seam driving and mining system is carried out; s40, selecting an inter-seam drive-production injection-production process, and establishing an implementation parameter optimization method; s50, construction parameters are determined; and S60, fracturing design and on-site construction are carried out. According to the method, through volume fracturing and an inter-seam driving and mining development mode, an inter-seam driving and mining full-life-cycle process parameter optimization method is formed, and the problem that the depletion type development recovery rate of the tight oil reservoir is low is solved; by selecting an inter-seam drive-production injection-production process, an implementation parameter optimization method is established, and energy supplementation of the horizontal well in the whole life cycle is achieved; the method has universality for tight oil reservoirs, the method is used for constructing driving and production fracturing design suitable for different reservoirs, the method can be popularized to different tight oil blocks, and the crude oil yield and recovery efficiency are effectively improved.

Description

TECHNICAL FIELD

[0001] The present application relates to the technical field of oil development, and particularly relates to a recovery improvement method and device for horizontal well volume fracturing development and a medium. BACKGROUND

[0002] Some oilfields in China have poor reservoir physical properties and strong heterogeneity, and in order to realize efficient development, pilot tests of water flooding in vertical wells are carried out in the early stage, but water channeling occurs rapidly along the direction of the maximum principal stress after water flooding, and some oil production wells are rapidly watered out only one month after being put into production, so the water flooding development effect is poor. From 2015 to 2016, the development concept of unconventional reservoirs in North America was learned, and the main development technology of horizontal well + volume fracturing quasi-natural energy development was gradually established as the core, so that the reservoirs were effectively developed, but the production declined rapidly in the late development stage due to lack of energy supplement, and the development effect was not ideal, so it is urgent to change the development concept and improve the recovery of the block.

[0003] At present, the recovery of oilfield conglomerate reservoirs is low, and mainly faces two problems, one is how to optimize the development mode, and the other is how to optimize the process and parameters to realize the optimization of the development mode, so as to improve the recovery.

[0004] For the tight conglomerate reservoir of an oilfield, the fractures generated by horizontal well multi-stage fracturing greatly increase the swept area of injected fluid and reservoir, and the injection of fluid into the reservoir through the fractures can effectively solve the problem of injection difficulty, and some people have proposed the inter-slit oil displacement technology in segmented fracturing horizontal wells, one slit in the segmented fracturing horizontal well is used as an injection slit, and the two adjacent slits are used as oil production slits, and the injected water / natural gas / CO2 can drive the oil to the adjacent slits to achieve the displacement purpose. Cheng Shiqing et al. also carried out similar research, which proved that the inter-slit displacement improved the recovery effect. On this basis, researchers further found that the inter-slit oil displacement in segmented fracturing horizontal wells can be divided into inter-slit continuous oil displacement and inter-slit periodic injection oil displacement. The two studies show that the inter-slit displacement or inter-slit huff and puff recovery of segmented fracturing horizontal wells can be improved by more than 20%. The inter-slit synchronous injection and production and inter-slit asynchronous injection and production methods are feasible in improving the production of multi-stage fracturing horizontal well groups in unconventional reservoirs.

[0005] In the prior art, the application number CN105937388A discloses a compacted sandstone reservoir integrated development method, which adopts horizontal well row well pattern for development, the wellbore trajectory of each horizontal well is perpendicular to the direction of the maximum horizontal principal stress of the stratum, the middle horizontal well is used for large-scale volume fracturing injection of fracturing fluid and proppant, the stratum energy is supplemented through the fracturing fluid, the proppant supports the fracturing cracks, the middle horizontal well is fractured and put into production, and the development mode of the two side horizontal wells is perforated and put into production, which considers the reconstruction of the reservoir and effectively supplements the stratum energy, realizes the integration of fracturing reconstruction and water injection energy supplement, and can effectively reduce the production decline rate and improve the oilfield recovery ratio while ensuring the single well production of the horizontal well is improved.

[0006] However, the method fails to focus on specific reservoirs to carry out targeted injection and production parameter optimization, and cannot solve the problem of low recovery ratio of the compacted reservoir in the depletion development. SUMMARY

[0007] The main purpose of the present application is to provide a horizontal well volume fracturing development method, device and medium for improving recovery ratio, so as to solve the problem of low recovery ratio of the compacted reservoir in the depletion development in the prior art.

[0008] To achieve the above purpose, the present application provides a horizontal well volume fracturing development method for improving recovery ratio, which comprises the following steps: S10, obtaining target reservoir basic parameters; S20, determining volume fracturing and inter-fracture distance drive production development mode; S30, optimizing inter-fracture drive production system parameters; S40, selecting inter-fracture drive production injection and production technology, and establishing an implementation parameter optimization method; S50, determining construction parameters; and S60, performing fracturing design and field construction.

[0009] Optionally, the target reservoir basic parameters comprise fluid characteristics, geological parameters and engineering characteristics, wherein the fluid characteristics comprise reservoir type, oil layer distribution and temperature and pressure, the geological parameters comprise lithology, physical property, rock mechanics property and natural fracture development condition, and the engineering characteristics comprise previous fracturing condition.

[0010] Optionally, the step S20 comprises the following steps: S210, determining injection fracture and production fracture positions based on the horizontal well volume fracturing, and establishing inter-fracture short distance drive production relationship; and S220, determining the volume fracturing and inter-fracture distance drive production development mode based on the inter-fracture short distance drive production relationship.

[0011] Optionally, step S30 includes the following steps: S310, performing reservoir numerical simulation to establish a non-uniform grid integrated oil-water two-phase flow model of "injection-flooding-production"; S320, determining the ratio of water injection fracture length to hydraulic fracture length, cluster spacing, quantity ratio, sand content per fracture in sand-added fractures, and well shut-in time; S330, establishing a fracture network parameter optimization design template based on different reservoir well network spacing, physical properties, and oil layer thickness; S340, optimizing the parameters of the fracture flooding system.

[0012] Optionally, the construction parameters include the pumping process, discharge rate, and the volume of fluid injected into and extracted from the fracture.

[0013] Optionally, step S60 includes the following steps: S610, performing fracturing operations on each section of the horizontal well sequentially using a bridge-perforation combined operation process; S620, pumping fracturing fluid and proppant at the perforation location in the production section; S630, pumping only fracturing fluid at the injection section location.

[0014] Optionally, in step S630, the fracturing fluid includes a matching nano-displacement agent and CO2.

[0015] Optionally, after step S60, the following step is also included: S70, if the reservoir pressure decreases during the later production process, a coiled tubing bottom-sealed single-clamp tool is used to fracturing and inject fluid into the fracture.

[0016] Furthermore, to achieve the above objectives, this application also provides an enhanced oil recovery device for horizontal well volumetric fracturing development. The device includes a parameter acquisition module, a mode determination module, a parameter optimization module, a method optimization module, and a fracturing design module. The parameter acquisition module is used to acquire basic parameters of the target reservoir; the mode determination module is used to determine the volumetric fracturing and inter-fracture fracturing development modes; the parameter optimization module is used to optimize the inter-fracture fracturing system parameters; the method optimization module is used to select the inter-fracture fracturing injection-production process and establish an implementation method for parameter optimization; the parameter determination module is used to determine the construction parameters; and the fracturing design module is used to perform fracturing design and on-site construction.

[0017] In addition, to achieve the above objectives, embodiments of this application also provide a computer-readable storage medium including instructions that, when executed on a computer, cause the computer to perform an enhanced oil recovery method for horizontal well volumetric fracturing development according to any embodiment of this application.

[0018] Furthermore, to achieve the above objectives, embodiments of this application also provide a computing device, which includes at least one processor, a memory, and an input / output unit; wherein the memory is used to store computer programs, and the processor is used to call the computer programs stored in the memory to execute the enhanced oil recovery method for horizontal well volumetric fracturing development according to any embodiment of this application.

[0019] Compared with the prior art, the beneficial effects of the present invention are as follows:

[0020] The improved oil recovery method for horizontal well volumetric fracturing development provided in this application embodiment forms a method for optimizing process parameters throughout the entire life cycle of fractured well development through volumetric fracturing and fractured well production development modes, in order to solve the problem of low recovery rate in depletion-type development of tight oil reservoirs. By selecting fractured well production injection and production processes and establishing an implementation parameter optimization method, energy replenishment is achieved throughout the entire life cycle of horizontal wells. This method is universal for tight oil reservoirs, and by using this method to construct fracturing designs suitable for different reservoirs, it can be extended to different tight oil blocks, effectively improving crude oil production and recovery rate. Attached Figure Description

[0021] Figure 1 A flowchart illustrating an enhanced oil recovery method for horizontal well volumetric fracturing development provided in this application embodiment;

[0022] Figure 2 A structural block diagram of an enhanced oil recovery device for horizontal well volumetric fracturing provided in this application embodiment;

[0023] Figure 3 This is a schematic diagram of the structure of the medium provided in the embodiments of this application;

[0024] Figure 4 A schematic diagram of the structure of a computing device provided in an embodiment of this application.

[0025] Explanation of reference numerals in the attached figures:

[0026] 200-Enhanced oil recovery device for horizontal well volumetric fracturing development, 210-Parameter acquisition module, 220-Mode determination module, 230-Parameter optimization module, 240-Method optimization module, 250-Parameter determination module, 260-Fracturing design module.

[0027] The realization of the purpose, functional features and advantages of this application will be further explained in conjunction with the embodiments and with reference to the accompanying drawings. Detailed Implementation

[0028] It should be understood that the specific embodiments described herein are merely illustrative and not intended to limit the scope of the application. Rather, these embodiments are provided to make the disclosure more thorough and complete, and to fully convey the scope of the disclosure to those skilled in the art.

[0029] To address the aforementioned technical problems, this application provides a method for enhancing oil recovery in horizontal well volumetric fracturing development. This method can be executed by a computer, such as... Figure 1 As shown, the method may include the following steps:

[0030] S10, obtain the basic parameters of the target reservoir.

[0031] Specifically, the basic parameters of the target reservoir include fluid characteristics, geological parameters, and engineering characteristics. Among them, fluid characteristics include reservoir type, oil layer distribution, and temperature and pressure; geological parameters include lithology, physical properties, rock mechanical properties, and natural fracture development; and engineering characteristics include the previous fracturing situation.

[0032] S20, determine the volumetric fracturing and fracture spacing-driven development mode.

[0033] In an exemplary embodiment, step S20 may include the following steps:

[0034] Step S20 includes the following steps:

[0035] S210, based on horizontal well volumetric fracturing, determines the location of injection and production fractures and establishes short-distance drive-production relationships between fractures;

[0036] S220 determines the volumetric fracturing and inter-fracture spacing fracturing development modes based on the short-distance fracturing relationship between fractures.

[0037] Specifically, during fracturing, sand fracturing is performed on the production fractures, and large-scale fluid injection is used for the displacement fractures. The sand-fracturing fractures and fluid injection fractures are distributed alternately and meet certain quantitative requirements. In addition, during production, the high-pressure fluid from the fluid injection fractures drives the crude oil towards the sand-fracturing fractures, achieving short-distance fracturing and production between fractures.

[0038] S30, optimize the parameters of the inter-slit mining system.

[0039] In an exemplary embodiment, step S30 may specifically include the following steps:

[0040] S310, conduct reservoir numerical simulation and establish a non-uniform grid integrated oil-water two-phase flow model of "pressure-injection-drive-production";

[0041] S320, determine the ratio of water injection fracture length to hydraulic fracture length, cluster spacing, quantity ratio, amount of sand per fracture, and well shut-in time;

[0042] S330, based on different reservoir well spacing, physical properties and oil layer thickness, establishes a template for optimizing the design of fracture network parameters for fractured flooding.

[0043] S340, optimize the parameters of the inter-slit mining system.

[0044] In step S310, reservoir numerical simulation refers to using a computer to solve the reservoir mathematical model, simulating underground oil and water flow, and providing the oil and water distribution at a certain moment to predict reservoir dynamics. Furthermore, the non-uniform grid integrated oil-water two-phase flow model for "injection-flooding-production" is based on an unstructured grid, which to some extent overcomes the limitations of conventional triangular, rectangular, and other structured grids. By adjusting the grid shape, grid independence can be verified, and the accuracy of the flow field simulation can be improved. Based on the accurate flow field simulation, the entire process of oil production fracture-displacement fracture morphology design, fracturing fluid injection, well shut-in displacement, well opening production, and secondary energy replenishment is simulated.

[0045] Furthermore, when developing new blocks, the design template can be matched according to the characteristics of the block reservoir, and the appropriate fracture network parameters can be quickly determined based on the correspondence between reservoir parameters and engineering parameters, thus guiding the fracturing engineering design.

[0046] S40, select the fractured well injection-production process and establish a method for optimizing implementation parameters to achieve energy replenishment throughout the entire life cycle of horizontal wells.

[0047] Specifically, this embodiment is based on the bridge plug perforation combined operation process. The produced fracture is fracturing with sand to generate a high-conductivity support fracture, opening up a channel for oil and gas flow and realizing the effective utilization of the reservoir; the injected fracture is not fracturing with sand, the fracture closes naturally, and the absence of flow capacity achieves water retention and pressure maintenance.

[0048] Furthermore, during the production process, the formation crude oil achieves short-distance displacement between the injection and sand-addition fractures under the pressure difference.

[0049] S50, determine the construction parameters.

[0050] The construction parameters include pumping process, discharge rate, and the volume of fluid injected into and extracted from the injection and extraction joints.

[0051] In this exemplary embodiment, to ensure the long-term effectiveness of the fracture-based flooding system, it is necessary to control the length of the injection fractures, reduce the risk of connecting to adjacent wells, and improve the flooding effect. The design employs a "low-viscosity fracture initiation + small-volume fluid replenishment" pump injection process. Taking a certain block as an example: the optimized displacement during the fracture initiation stage is 5-6 m³ / h. 3 / min, fluid replenishment phase 2-4m 3 / min.

[0052] S60, for fracturing design and on-site construction.

[0053] In an exemplary embodiment, step S60 may specifically include the following steps:

[0054] S610 employs a bridge-shooting combined fracturing process to sequentially perform fracturing operations on each section of the horizontal well.

[0055] S620, pump fracturing fluid and proppant into the perforation location of the produced section;

[0056] The S630 pumps only fracturing fluid at the injection section. The fracturing fluid includes a matching nano-displacement agent and CO2 (carbon dioxide). Other displacement media can also be used to improve the displacement effect.

[0057] In an exemplary embodiment, after step S60, the following steps may also be included:

[0058] S70, if the reservoir pressure decreases during the later production process, use a coiled tubing bottom with double-seal single-clamp tool to fracturing and inject fluid into the fracture.

[0059] Specifically, by using a coiled tubing bottom-mounted double-seal single-clamp tool to re-fracture the injection fracture, precise energy replenishment can be achieved, thus enabling efficient injection and production throughout the entire lifecycle of the oil and gas well. The injection fluid can be equipped with matching nano-displacement agents, CO2, or other oil displacement media to enhance the oil displacement effect.

[0060] The following analysis will use specific examples to further illustrate this point:

[0061] (1) Organize and analyze data such as reservoir type, reservoir characteristics, temperature and pressure system, fluid properties, reservoir sensitivity, oil testing and production, rock mechanical properties, natural fracture development, previous hydraulic fracturing, and development history data of the block to determine reservoir stimulation needs and principles.

[0062] (2) Determining the fracture spacing displacement development model. Based on previous reservoir development practices and geological characteristics, numerical simulations were conducted to predict production indicators and economic benefits. The optimal displacement distance between fractures was determined to be 30m, achieving high recovery rates and economic benefits. Simultaneously, a single injection-production unit consisting of one injection fracture + one production fracture, one injection fracture + two production fractures, or one injection fracture + three production fractures can all achieve the goal of improving recovery rates through fracture displacement. However, the displacement effect significantly decreases when the number of fractures is greater than or equal to four. Based on engineering practice and economic benefit evaluation, using three clusters within a section can achieve a more balanced fracture propagation effect while maintaining relatively low cost. Therefore, the production section was designed with three clusters within the section and a cluster spacing of 30m; the injection section had one cluster within the section and a cluster spacing of 30m.

[0063] (3) Optimization of parameters for the fractured flooding and production system. This mainly involved reservoir numerical simulation, establishing a non-uniform grid integrated oil-water two-phase flow model for "injection-flooding-production". Based on the numerical simulation, the ratio of injection fracture length to hydraulic fracture length was determined to be 0.8, the injection volume per injection fracture was 0.08 PV, the fluid volume per produced fracture was 0.1 PV, and the sand volume per fracture was 50 m³. 3 Good results can be achieved. Based on the well spacing, physical properties, and oil layer thickness of different reservoirs, a template for designing fracture network parameters for fracture-driven production can be established to guide different reservoirs in enhancing oil recovery and increasing economic benefits.

[0064] (4) Select the inter-fracture fracturing injection-production process and establish a method for optimizing implementation parameters. Currently, the main method used in tight oil reservoirs in the Junggar Basin is bridge plug perforation combined fracturing, which has advantages such as low cost, large-scale modification capability, and adaptability to factory-style operations. The design adopts the bridge plug perforation combined fracturing process, where the produced fractures are fractured with proppant to create high-conductivity support fractures, opening up oil and gas flow channels and achieving effective reservoir utilization; the injection fractures are not fractured with proppant, the fractures close naturally, and the lack of conductivity achieves water retention and pressure maintenance. During production, the formation crude oil is displaced over short distances between the injection and proppant fractures under the pressure difference.

[0065] (5) Determine construction parameters. To ensure the long-term effectiveness of the fracture-driven production system, the length of the injection fractures needs to be controlled to reduce the risk of connecting to adjacent wells. The injection section is designed to use a "low-viscosity fracture initiation + small-volume replenishment" pump injection process. Based on the numerical simulation of fracture propagation in this block, each injection section consists of one cluster, and the optimized displacement during the fracture initiation stage is 3-4 m³ / s. 3 / min, fluid replenishment phase 1-2m 3 / min; Design injection volume per slit: 2000m³ 3 The fluid volume extracted from a single suture joint is 1000m³. 3 A 15-day post-pressure well-sealing period yields good flooding and production results. Based on previous development experience, it was determined that high-viscosity fracturing should be used in the sand-adding section, with a single-fracturing discharge rate of 5 m³ / min, 3 clusters per section, and a construction discharge rate of 15 m³ / min for the sand-adding section.

[0066] (6) Based on the optimization results of the above steps, fracturing design and on-site construction were carried out. Quartz sand was selected as the proppant, and a non-mixed variable viscosity fracturing fluid system was selected as the fracturing fluid. The bridge-perforation combined operation process was used to carry out fracturing construction on each section of the horizontal well in sequence: fracturing fluid and proppant were pumped at the perforation position of the production section, and only fracturing fluid was pumped at the injection section. Taking well X as an example, the design adopted 3 clusters / 1 cluster within the section, with an actual cluster spacing of 30m, a spacing of 90m between the sand-added sections, and a spacing of 30m between the non-sand-added sections. The horizontal section of this well is 1050m long and divided into 17 sections. This time, nano-oil displacement agent was added to the fracturing fluid to improve the oil displacement effect. Sections 1, 3, 5, 7, 9, 11, 13, 15, and 17 were designed as sand-added sections, with a sand-added volume of 150m per section. 3 Single-stage liquid volume 3000m 3 The design discharge rate for the sand-adding section is 15 m³ / min; sections 2, 4, 6, 8, 10, 12, 14, and 16 are sand-free sections with a single-section flow rate of 2000 m³ / min. 3 The designed discharge volume for the opening stage of the non-sand-filled section is 3-4 m³ / h. 3 / min, fluid replenishment phase 1-2m 3 / min. After fracturing, the well should be kept closed for 15 days before production can begin.

[0067] (7) If the reservoir pressure decreases during later production, a double-sealed single-clamp tool with coiled tubing at the bottom can be used to re-fracture the injection fracture. Taking well X as an example, according to reservoir numerical simulation, immediate refueling after shutdown has good full life cycle production effect and economic benefits. After two years of production, well X shut down and switched to pumping. According to the production profile test, there is a lot of remaining oil in sections 1, 5, 11, 13, and 15; according to reservoir numerical simulation, refueling is needed for sections 2, 10, 12, 14, and 16 at 1900, 2400, 2300, 3000, and 2500 m³, respectively. 3 Good results can be achieved. Based on core laboratory experiments, reservoir numerical simulation, and economic benefit calculations, CO2 injection can enhance the energy enhancement effect and utilize crude oil with smaller pores, further improving the recovery rate. The design pre-injects 300t of carbon dioxide into each section before fluid injection. The design uses 6000m×Φ50.3mm continuous tubing with a double-seal single-clamp tool to provide energy replenishment for key well groups in sections 2, 10, 12, 14, and 16, with a replenishment flow rate of 0.8m³ / min and single-cluster replenishment of 1900, 2400, 2300, 3000, and 2500m³. 3 Each section is pre-injected with 300t of carbon dioxide; the remaining sections with less oil are replenished with 1000m³ of liquid per cluster. 3 No carbon dioxide is pre-filled. After recharging, the well is shut in for 15 days before production begins.

[0068] The improved oil recovery method for horizontal well volumetric fracturing development provided in this application embodiment forms a method for optimizing process parameters throughout the entire life cycle of fractured well development through volumetric fracturing and fractured well production development modes, in order to solve the problem of low recovery rate in depletion-type development of tight oil reservoirs. By selecting fractured well production injection and production processes and establishing an implementation parameter optimization method, energy replenishment is achieved throughout the entire life cycle of horizontal wells. This method is universal for tight oil reservoirs, and by using this method to construct fracturing designs suitable for different reservoirs, it can be extended to different tight oil blocks, effectively improving crude oil production and recovery rate.

[0069] Based on the above embodiments, refer to Figure 2 Another embodiment of this application also provides an enhanced oil recovery device for horizontal well volumetric fracturing development. This enhanced oil recovery device 200 for horizontal well volumetric fracturing development may include the following modules:

[0070] Parameter acquisition module 210 is used to acquire basic parameters of the target reservoir;

[0071] The mode determination module 220 is used to determine the volumetric fracturing and fracture spacing-driven development modes.

[0072] Parameter optimization module 230 is used to optimize the parameters of the inter-seam extraction system;

[0073] The method optimization module 240 is used to select the inter-seam injection-production process and establish an implementation parameter optimization method;

[0074] Parameter determination module 250 is used to determine construction parameters;

[0075] The fracturing design module 260 is used for fracturing design and on-site construction.

[0076] Based on the above embodiments, this application also provides a computer-readable storage medium, see reference. Figure 3 The computer-readable storage medium shown is an optical disc 50, on which a computer program (i.e., a program product) is stored. When the computer program is run by a processor, it will implement the steps described in the above-described method implementation, such as: obtaining basic parameters of the target reservoir; determining the volumetric fracturing and fracture spacing drive-production development mode; optimizing the parameters of the fracture spacing drive-production system; selecting the fracture spacing drive-production injection-production process and establishing a method for optimizing the implementation parameters; determining the construction parameters; and performing fracturing design and on-site construction. The specific implementation methods of each step will not be repeated here.

[0077] It should be noted that examples of computer-readable storage media may also include, but are not limited to, phase-change memory (PRAM), static random access memory (SRAM), dynamic random access memory (DRAM), other types of random access memory (RAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), flash memory or other optical and magnetic storage media, which will not be elaborated here.

[0078] Furthermore, based on the above embodiments, this application also provides a computing device. Figure 4 A block diagram is shown of an exemplary computing device 60 suitable for implementing embodiments of the present application. The computing device 60 may be a computer system or a server. Figure 4 The computing device 60 shown is merely an example and should not impose any limitation on the functionality and scope of use of the embodiments of this application.

[0079] like Figure 4 As shown, the components of computing device 60 may include, but are not limited to: one or more processors or processing units 601, system memory 602, and bus 603 connecting different system components (including system memory 602 and processing unit 601).

[0080] The computing device 60 typically includes a variety of computer system readable media. These media can be any available media that can be accessed by the computing device 60, including volatile and non-volatile media, removable and non-removable media.

[0081] System memory 602 may include computer system readable media in the form of volatile memory, such as random access memory (RAM) 6021 and / or cache memory 6022. Computing device 60 may further include other removable / non-removable, volatile / non-volatile computer system storage media. By way of example only, ROM 6023 may be used to read and write non-removable, non-volatile magnetic media (…). Figure 4 (Not shown in the image, usually referred to as "hard drive"). Although not shown in Figure 4 The diagram illustrates that disk drives for reading and writing to removable non-volatile disks (e.g., "floppy disks") and optical disc drives for reading and writing to removable non-volatile optical discs (e.g., CD-ROMs, DVD-ROMs, or other optical media) can be provided. In these cases, each drive can be connected to a bus 603 that connects different system components via one or more data media interfaces. The system memory 602 may include at least one program product having a set (e.g., at least one) of program modules configured to perform the functions of the embodiments of this application.

[0082] A program / utility 6025 having a set (at least one) of program modules 6024 may be stored, for example, in system memory 602, and such program modules 6024 include, but are not limited to, an operating system, one or more application programs, other program modules, and program data, each or some combination of these examples may include an implementation of a network environment. Program modules 6024 typically perform the functions and / or methods described in the embodiments of this application.

[0083] The computing device 60 can also communicate with one or more external devices 604 (such as a keyboard, pointing device, display, etc.). This communication can be performed via the input / output (I / O) interface 605. Furthermore, the computing device 60 can also communicate with one or more networks (e.g., local area networks (LANs), wide area networks (WANs), and / or public networks, such as the Internet) via a network adapter 606. Figure 4 As shown, network adapter 606 communicates with other modules of computing device 60 (such as processing unit 601, etc.) via bus 603, which connects different system components. It should be understood that, although... Figure 4 As not shown, it can be used in conjunction with computing device 60 with other hardware and / or software modules.

[0084] The processing unit 601 executes various functional applications and data processing by running programs stored in the system memory 602. For example, it acquires basic parameters of the target reservoir; determines volumetric fracturing and fracture-spaced fracturing development modes; optimizes fracture-spaced fracturing system parameters; selects fracture-spaced fracturing injection-production technology and establishes implementation parameter optimization methods; determines construction parameters; and performs fracturing design and on-site construction. The specific implementation methods of each step will not be repeated here. It should be noted that although several units / modules or sub-units / sub-modules of the enhanced oil recovery device for horizontal well volumetric fracturing development are mentioned in the detailed description above, this division is merely exemplary and not mandatory. In fact, according to the embodiments of this application, the features and functions of two or more units / modules described above can be embodied in one unit / module. Conversely, the features and functions of one unit / module described above can be further divided into multiple units / modules.

[0085] In the description of this application, it should be noted that the terms "first", "second", and "third" are used for descriptive purposes only and should not be construed as indicating or implying relative importance.

[0086] Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the specific working processes of the systems, devices, and units described above can be referred to the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0087] In the several embodiments provided in this application, it should be understood that the disclosed systems, apparatuses, and methods can be implemented in other ways. The apparatus embodiments described above are merely illustrative; for example, the division of units is only a logical functional division, and in actual implementation, there may be other division methods. Furthermore, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Additionally, the coupling or direct coupling or communication connection shown or discussed may be through some communication interface; the indirect coupling or communication connection between apparatuses or units may be electrical, mechanical, or other forms.

[0088] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of this embodiment according to actual needs.

[0089] In addition, the functional units in the various embodiments of this application can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit.

[0090] If a function is implemented as a software functional unit and sold or used as an independent product, it can be stored in a processor-executable, non-volatile, computer-readable storage medium. Based on this understanding, the technical solution of this application, in essence, or the part that contributes to the prior art, or a part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods of the various embodiments of this application. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0091] Finally, it should be noted that the above embodiments are merely specific implementations of this application, used to illustrate the technical solutions of this application, and not to limit them. The protection scope of this application is not limited thereto. Although this application has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that any person skilled in the art can still modify or easily conceive of changes to the technical solutions described in the foregoing embodiments, or make equivalent substitutions for some of the technical features, within the technical scope disclosed in this application. Such modifications, changes, or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of this application, and should all be covered within the protection scope of this application. Therefore, the protection scope of this application should be determined by the protection scope of the claims.

[0092] Furthermore, although the operations of the method of this application are described in a specific order in the accompanying drawings, this does not require or imply that these operations must be performed in that specific order, or that all the operations shown must be performed to achieve the desired result. Additionally or alternatively, certain steps may be omitted, multiple steps may be combined into one step, and / or one step may be broken down into multiple steps.

Claims

1. A method for enhancing oil recovery in horizontal well volumetric fracturing development, characterized in that, The method includes the following steps: S10, Obtain basic parameters of the target reservoir; S20, determine the volumetric fracturing and fracture spacing-driven development mode; S30, optimize the parameters of the inter-slit mining system; S40, Select the inter-seam injection-production process and establish a method for optimizing implementation parameters; S50, determine the construction parameters; S60, for fracturing design and on-site construction.

2. The method for enhancing oil recovery in horizontal well volumetric fracturing development according to claim 1, characterized in that, The basic parameters of the target reservoir include fluid characteristics, geological parameters, and engineering characteristics. The fluid characteristics include reservoir type, oil layer distribution, and temperature and pressure. The geological parameters include lithology, physical properties, rock mechanical properties, and the development of natural fractures. The engineering characteristics include the previous hydraulic fracturing situation.

3. The method for enhancing oil recovery in horizontal well volumetric fracturing development according to claim 1, characterized in that, Step S20 includes the following steps: S210, based on horizontal well volumetric fracturing, determines the location of injection and production fractures and establishes short-distance drive-production relationships between fractures; S220, Based on the short-distance fracturing relationship between the fractures, determine the volumetric fracturing and inter-fracture spacing fracturing development modes.

4. The method for enhancing oil recovery through volumetric fracturing in horizontal wells according to claim 1, characterized in that, Step S30 includes the following steps: S310, conduct reservoir numerical simulation and establish a non-uniform grid integrated oil-water two-phase flow model of "pressure-injection-drive-production"; S320, determine the ratio of water injection fracture length to hydraulic fracture length, cluster spacing, quantity ratio, amount of sand per fracture, and well shut-in time; S330, based on different reservoir well spacing, physical properties and oil layer thickness, establishes a template for optimizing the design of fracture network parameters for fractured flooding. S340, optimize the parameters of the inter-slit mining system.

5. The method for enhancing oil recovery in horizontal well volumetric fracturing development according to claim 1, characterized in that, The construction parameters include the pumping process, discharge rate, and the volume of fluid injected into and extracted from the injection and extraction seams.

6. The method for enhancing oil recovery in horizontal well volumetric fracturing development according to claim 1, characterized in that, Step S60 includes the following steps: S610 employs a bridge-shooting combined fracturing process to sequentially perform fracturing operations on each section of the horizontal well. S620, pump fracturing fluid and proppant into the perforation location of the produced section; S630 pumps only fracturing fluid at the injection section.

7. The method for enhancing oil recovery in horizontal well volumetric fracturing development according to claim 6, characterized in that, In step S630, the fracturing fluid includes a matching nano-displacement agent and CO2.

8. The method for enhancing oil recovery in horizontal well volumetric fracturing development according to claim 1, characterized in that, Following step S60, the following steps are also included: S70, if the reservoir pressure decreases during the later production process, use a coiled tubing bottom with double-seal single-clamp tool to fracturing and inject fluid into the fracture.

9. An enhanced oil recovery device for horizontal well volumetric fracturing development, characterized in that, include: The parameter acquisition module is used to acquire basic parameters of the target reservoir; The mode determination module is used to determine the volumetric fracturing and fracture spacing-driven development modes; The parameter optimization module is used to optimize the parameters of the inter-seam extraction system. The method optimization module is used to select the inter-seam injection-production process and establish an implementation parameter optimization method. The parameter determination module is used to determine construction parameters; The fracturing design module is used for fracturing design and on-site construction.

10. A computer-readable storage medium, characterized in that, It includes instructions that, when executed on a computer, cause the computer to perform the enhanced oil recovery method for horizontal well volumetric fracturing development as described in any one of claims 1 to 8.

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