Oil reservoir recovery degree determination method, device and equipment and storage medium

Abstract

The invention discloses an oil reservoir recovery degree determination method, device and equipment and a storage medium. The method comprises the steps that first rock core test data of a first rock core sample and second rock core test data of a second rock core sample are obtained, the first rock core sample is obtained by vacuumizing a target rock core sample and pressurizing saturated water, and the second rock core sample is obtained by conducting oil displacement water saturation on the first rock core sample to establish bound water; determining a target inter-well distance of the target exploration area, and determining a plurality of displacement pressure gradients of different oil reservoir positions of the target exploration area and a displacement range corresponding to each displacement pressure gradient; and based on the first rock core test data, the second rock core test data, the target inter-well distance, the multiple displacement pressure gradients and the displacement range corresponding to each displacement pressure gradient, the oil reservoir recovery degree is determined. According to the method, the oil reservoir recovery degree can be efficiently determined, the accuracy of determining the oil reservoir recovery degree is improved, and the oil reservoir development requirement is met.

Description

Technical Field

[0001] This invention relates to the field of reservoir development technology, and in particular to a method, apparatus, equipment and storage medium for determining the degree of reservoir recovery. Background Technology

[0002] For oil reservoir exploration and development, the actual benefits that the reservoir can bring are crucial. Therefore, accurately estimating the recovery rate of the reservoir before it officially goes into production is of great significance for reservoir development.

[0003] Currently, traditional methods for determining reservoir recovery levels primarily utilize artificial intelligence technology to analyze reservoir physical parameters and oilfield production parameters to estimate the recovery level. However, these traditional methods suffer from low efficiency and accuracy, high costs, and cannot meet the needs of reservoir development, thereby reducing the production efficiency and economic benefits of reservoir development. Summary of the Invention

[0004] This invention provides a method, apparatus, equipment, and storage medium for determining the degree of oil reservoir recovery, thereby achieving efficient determination of the degree of oil reservoir recovery, greatly improving the efficiency and accuracy of oil reservoir recovery determination, significantly reducing costs, meeting the needs of oil reservoir development, and thus improving the production efficiency and economic benefits of oil reservoir development.

[0005] According to one aspect of the present invention, a method for determining the degree of oil reservoir recovery is provided, the method comprising: The first core test data corresponding to the first core sample and the second core test data corresponding to the second core sample of the target exploration area are obtained. The first core sample is obtained by vacuuming and pressurizing the target core sample with water, and the second core sample is obtained by oil-flooding water-saturated oil to establish bound water in the first core sample. Determine the target well distance in the target exploration area, and determine multiple displacement pressure gradients corresponding to different reservoir locations in the target exploration area, as well as the displacement range corresponding to each displacement pressure gradient; Based on the first core test data, the second core test data, the target well distance, multiple displacement pressure gradients, and the displacement range corresponding to each displacement pressure gradient, the oil reservoir recovery degree corresponding to the target exploration area is determined.

[0006] According to another aspect of the present invention, an apparatus for determining the degree of oil reservoir recovery is provided, the apparatus comprising: The data acquisition module is used to acquire the first core test data corresponding to the first core sample and the second core test data corresponding to the second core sample in the target exploration area. The first core sample is obtained by vacuuming and pressurizing the target core sample with water, and the second core sample is obtained by saturating the first core sample with oil-driven water to establish bound water. The pressure gradient determination module is used to determine the target well distance in the target exploration area, and to determine multiple displacement pressure gradients corresponding to different reservoir locations in the target exploration area and the displacement range corresponding to each displacement pressure gradient. The recovery degree determination module is used to determine the reservoir recovery degree corresponding to the target exploration area based on the first core test data, the second core test data, the target well distance, multiple displacement pressure gradients, and the displacement range corresponding to each displacement pressure gradient.

[0007] According to another aspect of the present invention, an electronic device is provided, the electronic device comprising: At least one processor; and A memory communicatively connected to the at least one processor; wherein, The memory stores a computer program that can be executed by the at least one processor, which enables the at least one processor to perform the reservoir recovery determination method according to any embodiment of the present invention.

[0008] According to another aspect of the present invention, a computer-readable storage medium is provided, the computer-readable storage medium storing computer instructions for causing a processor to execute and implement the reservoir recovery determination method according to any embodiment of the present invention.

[0009] The technical solution of this invention involves acquiring first core test data corresponding to a first core sample and second core test data corresponding to a second core sample from a target exploration area. The first core sample is obtained by vacuuming and pressurizing the target core sample with water, while the second core sample is obtained by saturating the first core sample with oil-flooded water to create bound water, providing a data foundation for subsequent steps. The invention also determines the target well distance within the target exploration area, and identifies multiple displacement pressure gradients corresponding to different reservoir locations within the target exploration area, as well as the displacement range corresponding to each displacement pressure gradient. Based on the first core test data, the second core test data, the target well distance, the multiple displacement pressure gradients, and the displacement range corresponding to each displacement pressure gradient, the invention determines the reservoir recovery degree within the target exploration area, improving the reliability of reservoir recovery degree determination. This invention obtains test data by conducting core experiments on first and second core samples. Combined with the well spacing and pressure gradient of the target exploration area, it quantifies the oil reservoir recovery degree of the target exploration area, achieving efficient determination of the oil reservoir recovery degree. This greatly improves the efficiency and accuracy of oil reservoir recovery degree determination, significantly reduces costs, meets the needs of oil reservoir development, provides a scientific basis for efficient oilfield development, and thus improves the production efficiency and economic benefits of oil reservoir development.

[0010] It should be understood that the description in this section is not intended to identify key or essential features of the embodiments of the present invention, nor is it intended to limit the scope of the invention. Other features of the invention will become readily apparent from the following description. Attached Figure Description

[0011] To more clearly illustrate the technical solutions in the embodiments of the present invention, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0012] Figure 1 This is a flowchart of a method for determining the degree of oil reservoir recovery according to Embodiment 1 of the present invention; Figure 2 This is a flowchart of a method for determining the degree of oil reservoir recovery according to Embodiment 2 of the present invention; Figure 3 This is an example diagram of the T2 spectrum of a core after different centrifugal displacement experiments according to Embodiment 2 of the present invention; Figure 4 This is an example diagram illustrating the relationship between the displacement pressure gradient at different reservoir locations and the distance between two wells and the center point, according to Embodiment 2 of the present invention. Figure 5 This is a schematic diagram of a reservoir recovery determination device according to Embodiment 3 of the present invention; Figure 6 This is a schematic diagram of the structure of an electronic device for implementing the method for determining the degree of oil recovery in an embodiment of the present invention. Detailed Implementation

[0013] To enable those skilled in the art to better understand the present invention, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of the present invention.

[0014] It should be noted that the terms "first," "second," "target," etc., used in the specification, claims, and accompanying drawings of this invention are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that embodiments of the invention described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover a non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0015] Example 1 Figure 1 This invention provides a flowchart of a method for determining the degree of oil reservoir recovery according to Embodiment 1. This embodiment is applicable to situations where the degree of oil reservoir recovery needs to be determined. This method can be executed by a reservoir recovery degree determination device, which can be implemented in hardware and / or software. This reservoir recovery degree determination device can be configured in an electronic device. Figure 1 As shown, the method includes: S110. Obtain the first core test data corresponding to the first core sample and the second core test data corresponding to the second core sample in the target exploration area. The first core sample is obtained by vacuuming and pressurizing the target core sample with water, and the second core sample is obtained by saturating the first core sample with oil-driven water to establish bound water.

[0016] The target exploration area can refer to a specific area where oil reservoir development is required. The first core sample can refer to the target core sample after vacuuming and pressurizing with saturated water. The first core test data can refer to data reflecting the pore fluid distribution and pore throat radius characteristics of the first core sample, such as the core T2 spectrum. The second core sample can refer to the first core sample after oil-driven water discharge to establish a bound water state. The second core test data can refer to data reflecting the pore fluid distribution and pore throat radius characteristics of the second core sample. The target core sample can refer to the original core sample after oil washing and drying to remove impurities and expose pores.

[0017] Specifically, core experiments can be conducted on the first core sample, such as core T2 spectrum testing, to obtain the first core test data corresponding to the first core sample in the target exploration area. Similarly, core experiments can be conducted on the second core sample, such as core T2 spectrum testing, to obtain the second core test data corresponding to the second core sample in the target exploration area. This can comprehensively reflect the stratigraphic characteristics and provide a data foundation for subsequent processing.

[0018] For example, S110 may include: washing and drying the original core sample of the target exploration area to obtain a target core sample; vacuuming and pressurizing the target core sample with saturated water to generate a first core sample, and performing a core T2 spectrum test on the first core sample to obtain the first core test data corresponding to the first core sample; performing oil-flooding water-saturated oil-to-bound water treatment on the first core sample to generate a second core sample, and performing a core T2 spectrum test on the second core sample to obtain the second core test data corresponding to the second core sample.

[0019] Specifically, the original core sample can be a representative core sample of the geological characteristics of the target exploration area. The original core sample can be washed with oil and then dried to obtain the target core sample. This process helps to completely remove residual oil and organic matter from the original core, avoiding interference from the oil-water mixed phase in subsequent experiments and ensuring the purity of the test data. The target core sample is then vacuumed and pressurized with water for saturation. After saturation, the resulting first core sample undergoes T2 spectral analysis to obtain the first core test data. Based on the first core sample, it is then treated with oil-flooding and water-saturated oil to establish bound water. After water-flooding, the resulting second core sample undergoes T2 spectral analysis to obtain the corresponding second core test data, thus providing basic parameters for the subsequent quantitative calculation of reservoir recovery.

[0020] S120. Determine the target well distance in the target exploration area, and determine the multiple displacement pressure gradients corresponding to different reservoir locations in the target exploration area, as well as the displacement range corresponding to each displacement pressure gradient.

[0021] The target well distance can refer to the straight-line distance between the production well and the injection well. The reservoir location can refer to the sampling points laid out along the well connection line. The displacement pressure gradient can refer to the pressure difference / centrifugal force per unit distance. The displacement range can refer to the distance between the displacement pressure gradient and the center point of the production well and the injection well.

[0022] Specifically, based on the location information of production wells and injection wells, the target well distance in the target exploration area can be determined. Based on the field production data and reservoir engineering methods, multiple displacement pressure gradients corresponding to different reservoir locations in the target exploration area and the displacement range corresponding to each displacement pressure gradient can be determined, providing data support for subsequent processing.

[0023] For example, S120 may include: determining the distance between production wells and injection wells in the target exploration area as the target well-to-well distance in the target exploration area, and sampling the well-to-well connection line between the production wells and injection wells to determine multiple reservoir locations in the target exploration area; and determining the displacement pressure gradient corresponding to each reservoir location and the displacement range corresponding to the displacement pressure gradient based on the target production data corresponding to the target exploration area and the multiple reservoir locations.

[0024] Among them, target production data can refer to the on-site production data of the oilfield in the target exploration area, covering multi-dimensional information such as production dynamics, geological engineering, and monitoring experiments.

[0025] Specifically, the three-dimensional coordinates of production wells and injection wells can be obtained from geological exploration data, and the straight-line distance between the two wells can be calculated, i.e., the target well-to-well distance in the target exploration area. Virtual sampling points are then set up along the connection line between the production wells and injection wells, with each sampling point corresponding to a reservoir location. This determines multiple reservoir locations in the target exploration area, providing a spatial reference for subsequent pressure gradient calculations. Based on the target production data and multiple reservoir locations corresponding to the target exploration area, combined with reservoir engineering methods such as Darcy's law or numerical simulation methods, the displacement pressure gradient at each reservoir location can be calculated. This yields the displacement pressure gradient corresponding to each reservoir location and determines the displacement range corresponding to each displacement pressure gradient, providing data support for subsequent steps and helping to improve the accuracy of reservoir recovery determination.

[0026] S130. Based on the first core test data, the second core test data, the target well distance, multiple displacement pressure gradients, and the displacement range corresponding to each displacement pressure gradient, determine the oil reservoir recovery degree corresponding to the target exploration area.

[0027] Among them, the oil reservoir recovery rate can refer to the percentage of cumulative oil production to geological reserves, reflecting the extraction efficiency.

[0028] Specifically, core displacement experiments can be used to simulate the oil displacement efficiency of the second core sample under different displacement pressure gradients. By combining the test data of the first core, the test data of the second core, the target well distance, and the displacement range corresponding to different displacement pressure gradients, the degree of oil recovery corresponding to the target exploration area can be determined, improving the efficiency and accuracy of determination and providing a scientific basis for the efficient development of oilfields.

[0029] In this embodiment, first core test data corresponding to the first core sample and second core test data corresponding to the second core sample of the target exploration area are obtained. The first core sample is obtained by vacuuming and pressurizing the target core sample with water, and the second core sample is obtained by saturating the first core sample with oil-flooding water to establish bound water. This provides a data basis for subsequent steps. The target well distance of the target exploration area is determined, as well as multiple displacement pressure gradients corresponding to different reservoir locations in the target exploration area and the displacement range corresponding to each displacement pressure gradient are determined. Based on the first core test data, second core test data, target well distance, multiple displacement pressure gradients, and the displacement range corresponding to each displacement pressure gradient, the reservoir recovery degree of the target exploration area is determined, improving the reliability of reservoir recovery degree determination. This invention obtains test data by conducting core experiments on first and second core samples. Combined with the well spacing and pressure gradient of the target exploration area, it quantifies the oil reservoir recovery degree of the target exploration area, achieving efficient determination of the oil reservoir recovery degree. This greatly improves the efficiency and accuracy of oil reservoir recovery degree determination, significantly reduces costs, meets the needs of oil reservoir development, provides a scientific basis for efficient oilfield development, and thus improves the production efficiency and economic benefits of oil reservoir development.

[0030] Example 2 Figure 2 This is a flowchart of a method for determining the degree of oil reservoir recovery provided in Embodiment 2 of the present invention. Based on the above embodiments, this embodiment optimizes the step of "determining the degree of oil reservoir recovery corresponding to the target exploration area based on first core test data, second core test data, target well-to-well distance, multiple displacement pressure gradients, and the displacement range corresponding to each displacement pressure gradient". Explanations of terms that are the same as or corresponding to those in the above embodiments are not repeated here.

[0031] See Figure 2 The alternative method for determining the degree of oil reservoir recovery provided in this embodiment specifically includes the following steps: S210. Obtain the first core test data corresponding to the first core sample and the second core test data corresponding to the second core sample in the target exploration area. The first core sample is obtained by vacuuming and pressurizing the target core sample with water, and the second core sample is obtained by saturating the first core sample with oil-driven water to establish bound water.

[0032] S220. Determine the target well distance in the target exploration area, and determine the multiple displacement pressure gradients corresponding to different reservoir locations in the target exploration area, as well as the displacement range corresponding to each displacement pressure gradient.

[0033] S230. Based on the first core test data, the second core test data, and multiple displacement pressure gradients, determine the degree of core extraction of the second core sample under each displacement pressure gradient.

[0034] Among them, the core recovery rate can refer to the percentage of the original saturated oil volume extracted from the core sample under a specific displacement pressure gradient.

[0035] Specifically, conventional waterflooding experiments can be conducted on the second core sample according to different displacement pressure gradients, and the T2 spectrum of the core sample after the experiment can be obtained. Combined with the test data of the first and second core samples, the waterflood recovery degree corresponding to each displacement pressure gradient can be calculated, that is, the core recovery degree of the second core sample under each displacement pressure gradient. The nonlinear relationship between the displacement pressure gradient and the recovery degree can be determined.

[0036] For example, S230 may include: determining the third core test data of the second core sample under each displacement pressure gradient based on multiple displacement pressure gradients; and determining the core recovery degree of the second core sample under each displacement pressure gradient based on the first core test data, the second core test data, and the third core test data.

[0037] Among them, the third core test data can refer to the data used to reflect the pore fluid distribution and pore throat radius characteristics of the second core sample after the displacement experiment.

[0038] Specifically, in the core displacement device, multiple displacement pressure gradients can be applied to the second core sample based on multiple displacement pressure gradients. After displacement is completed, T2 spectrum data is acquired using a low-field nuclear magnetic resonance spectrometer, and third core test data of the second core sample is obtained under each displacement pressure gradient. Multi-parameter coupling analysis is performed based on the first, second, and third core test data, and the core recovery degree of the second core sample under each displacement pressure gradient is determined based on the change in oil saturation. This allows for precise quantification of the core recovery degree under different pressure gradients, providing a basis for determining the subsequent reservoir recovery degree.

[0039] For example, based on multiple displacement pressure gradients, the third core test data of the second core sample under each displacement pressure gradient is determined, including: conducting water-drive oil centrifugation experiments on the second core samples under different displacement pressure gradients based on multiple displacement pressure gradients, and conducting core T2 spectrum tests on the second core samples under different displacement pressure gradients after the experiments, to determine the third core test data of the second core sample under each displacement pressure gradient.

[0040] Specifically, water-driven oil centrifugation experiments can be conducted on second core samples under different displacement pressure gradients based on multiple displacement pressure gradients. The centrifuge simulates the displacement process under different pressure gradients through centrifugal force. Immediately after the centrifugation displacement experiment, the core samples are transferred to a low-field nuclear magnetic resonance spectrometer. The core T2 spectrum of the second core samples under different displacement pressure gradients after the experiment is tested to obtain the third core test data of the second core samples under each displacement pressure gradient, providing a data basis for subsequent calculation of the core recovery degree.

[0041] For example, based on the first core test data, the second core test data, and the third core test data, determining the core recovery degree of the second core sample under each displacement pressure gradient includes: determining the saturated water state corresponding to the first core sample and the saturated oil state corresponding to the second core sample based on the first core test data and the second core test data; and determining the core recovery degree of the second core sample under each displacement pressure gradient based on the saturated water state, the saturated oil state, and the third core test data.

[0042] The term "saturated water state" refers to the physical state of a core sample after vacuuming and pressurizing to saturate with water, where the pores are completely filled with water. The term "saturated oil state" refers to the physical state of a core sample after oil-displacement treatment, where the pores are saturated with oil, building upon the saturated water state.

[0043] Specifically, the saturated water characteristics of the first core sample can be quantified using the first core test data, i.e., the saturated water state corresponding to the first core sample. The saturated oil characteristics of the second core sample can be quantified using the second core test data, i.e., the saturated oil state corresponding to the second core sample. The saturated water state, saturated oil state and the third core test data are coupled with multiple parameters to determine the core recovery degree of the second core sample under each displacement pressure gradient, providing a basis for the subsequent determination of the reservoir recovery degree.

[0044] S240. Based on the target well spacing, the displacement range corresponding to each displacement pressure gradient, and the core recovery degree, determine the reservoir recovery degree corresponding to the target exploration area.

[0045] Specifically, the reservoir recovery level of a target exploration area can be determined based on the target well-to-well distance, the displacement range corresponding to each displacement pressure gradient, and the core recovery level. By coupling well-to-well distance with displacement range, the core scale is extended to the reservoir scale, improving the practicality and accuracy of reservoir recovery level determination.

[0046] For example, the formula for calculating the recovery degree of the above-mentioned reservoir can be as follows: in, , , ... These represent the degree of core extraction under different displacement pressure gradients; , , ... These represent the displacement range under different displacement pressure gradients; The target well distance; This indicates the degree of oil recovery from the reservoir.

[0047] The technical solution of this embodiment determines the core recovery degree of a second core sample under each displacement pressure gradient by using first core test data, second core test data, and multiple displacement pressure gradients. This establishes a nonlinear relationship between the displacement pressure gradient and the recovery degree. Based on the target well-to-well distance, the displacement range corresponding to each displacement pressure gradient, and the core recovery degree, the reservoir recovery degree corresponding to the target exploration area is determined, improving the practicality and accuracy of reservoir recovery degree determination. This invention, through the quantification of core-scale recovery degree and the expansion of reservoir-scale recovery degree, combined with multi-parameter coupling of well-to-well distance, displacement pressure gradient, and displacement range, achieves comprehensive data integration from experimental to macro-engineering, greatly improving the efficiency and accuracy of reservoir recovery degree determination.

[0048] For example, to verify the technical effect of the present invention, a second core sample can be used to conduct water-drive oil centrifugation experiments on the rock sample under different displacement pressure gradients (centrifugal force) (e.g., water-drive oil centrifugation experiments using 1.57 psi, 3.21 psi, 15.51 psi, and 32.82 psi respectively), and nuclear magnetic resonance T2 spectrum tests can be performed on the core sample after the experiment. The T2 spectrum of the core sample after different centrifugal displacement experiments can be as follows: Figure 3 As shown in the figure. The relationship between the displacement pressure gradient at different reservoir locations and the distance between the two wells and the center point can be expressed as follows: Figure 4As shown, the recovery rate of rock samples under different displacement pressure gradients can be calculated using the displacement pressure gradients at different reservoir locations and the distance between the two wells and the center point (i.e., the displacement range). For example, the recovery rate of the core is 49% at a centrifugal force of 1.57 psi; 59% at 3.21 psi; 63% at 15.51 psi; and 65% at 32.82 psi; with displacement ranges of 60 / 60 / 24 / 6 respectively. The final recovery rate of the reservoir corresponding to the core is calculated using the formula: Example 3 Figure 5 This is a schematic diagram of a reservoir recovery determination device provided in Embodiment 3 of the present invention. Figure 5 As shown, the device includes: a data acquisition module 310, a pressure gradient determination module 320, and a recovery degree determination module 330; The data acquisition module 310 is used to acquire the first core test data corresponding to the first core sample and the second core test data corresponding to the second core sample in the target exploration area. The first core sample is obtained by vacuuming and pressurizing the target core sample with water, and the second core sample is obtained by saturating the first core sample with oil-driven water to establish bound water. The pressure gradient determination module 320 is used to determine the target well distance in the target exploration area, and to determine multiple displacement pressure gradients corresponding to different reservoir locations in the target exploration area and the displacement range corresponding to each displacement pressure gradient. The recovery degree determination module 330 is used to determine the reservoir recovery degree corresponding to the target exploration area based on the first core test data, the second core test data, the target well distance, multiple displacement pressure gradients, and the displacement range corresponding to each displacement pressure gradient.

[0049] In this embodiment, first core test data corresponding to a first core sample and second core test data corresponding to a second core sample in the target exploration area are obtained. The first core sample is obtained by vacuuming and pressurizing the target core sample with water, and the second core sample is obtained by saturating the first core sample with oil-flooding water to establish bound water. This provides a data basis for subsequent steps. The target well distance in the target exploration area is determined, as well as multiple displacement pressure gradients corresponding to different reservoir locations in the target exploration area and the displacement range corresponding to each displacement pressure gradient are determined. Based on the first core test data, the second core test data, the target well distance, the multiple displacement pressure gradients, and the displacement range corresponding to each displacement pressure gradient, the oil recovery degree corresponding to the target exploration area is determined, improving the reliability of the determination of the oil recovery degree. This invention obtains test data by conducting core experiments on first and second core samples. Combined with the well spacing and pressure gradient of the target exploration area, it quantifies the oil reservoir recovery degree of the target exploration area, achieving efficient determination of the oil reservoir recovery degree. This greatly improves the efficiency and accuracy of oil reservoir recovery degree determination, significantly reduces costs, meets the needs of oil reservoir development, provides a scientific basis for efficient oilfield development, and thus improves the production efficiency and economic benefits of oil reservoir development.

[0050] Optionally, the data acquisition module 310 is specifically used for: washing and drying the original core sample of the target exploration area to obtain a target core sample; vacuuming and pressurizing the target core sample with saturated water to generate a first core sample, and performing core T2 spectrum testing on the first core sample to obtain first core test data corresponding to the first core sample; performing oil-flooding water-saturated oil-building water treatment on the first core sample to generate a second core sample, and performing core T2 spectrum testing on the second core sample to obtain second core test data corresponding to the second core sample.

[0051] Optionally, the pressure gradient determination module 320 is specifically used to: determine the distance between production wells and injection wells in the target exploration area as the target well-to-well distance in the target exploration area, and sample the well-to-well connection line between the production wells and the injection wells to determine multiple reservoir locations in the target exploration area; based on the target production data corresponding to the target exploration area and the multiple reservoir locations, determine the displacement pressure gradient corresponding to each reservoir location and the displacement range corresponding to the displacement pressure gradient.

[0052] Optionally, the extraction degree determination module 330 includes: The core recovery degree determination unit is used to determine the core recovery degree of the second core sample under each displacement pressure gradient based on the first core test data, the second core test data and multiple displacement pressure gradients. The nano-element for determining the degree of oil recovery is used to determine the degree of oil recovery corresponding to the target exploration area based on the target well distance, the displacement range corresponding to each displacement pressure gradient, and the core recovery degree.

[0053] Optionally, the core extraction degree determination unit includes: The test data determination subunit is used to determine the third core test data of the second core sample under each displacement pressure gradient based on multiple displacement pressure gradients; The core recovery degree determination subunit determines the core recovery degree of the second core sample under each displacement pressure gradient based on the first core test data, the second core test data, and the third core test data.

[0054] Optionally, the test data determination subunit is specifically used for: conducting water-drive oil centrifugation experiments on the second core samples under different displacement pressure gradients based on multiple displacement pressure gradients, and conducting core T2 spectrum tests on the second core samples under different displacement pressure gradients after the experiments, to determine the third core test data of the second core samples under each displacement pressure gradient.

[0055] Optionally, the core recovery degree determination subunit is specifically used to: determine the saturated water state corresponding to the first core sample and the saturated oil state corresponding to the second core sample based on the first core test data and the second core test data; and determine the core recovery degree of the second core sample under each displacement pressure gradient based on the saturated water state, the saturated oil state, and the third core test data.

[0056] The above-mentioned device can execute the reservoir recovery degree determination method provided in any embodiment of the present invention, and has the corresponding functional modules and beneficial effects for executing the reservoir recovery degree determination method.

[0057] Example 4 Figure 6This is a schematic diagram of an electronic device for implementing the reservoir recovery determination method according to embodiments of the present invention. The electronic device 10 is intended to represent various forms of digital computers, such as laptop computers, desktop computers, workbenches, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The electronic device may also represent various forms of mobile devices, such as personal digital processors, cellular phones, smartphones, wearable devices (e.g., helmets, glasses, watches, etc.), and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely illustrative and are not intended to limit the implementation of the invention described and / or claimed herein.

[0058] like Figure 6 As shown, the electronic device 10 includes at least one processor 11 and a memory, such as a read-only memory (ROM) 12 or a random access memory (RAM) 13, communicatively connected to the at least one processor 11. The memory stores computer programs executable by the at least one processor. The processor 11 can perform various appropriate actions and processes based on the computer program stored in the ROM 12 or loaded into the RAM 13 from storage unit 18. The RAM 13 can also store various programs and data required for the operation of the electronic device 10. The processor 11, ROM 12, and RAM 13 are interconnected via a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0059] Multiple components in electronic device 10 are connected to I / O interface 15, including: input unit 16, such as keyboard, mouse, etc.; output unit 17, such as various types of displays, speakers, etc.; storage unit 18, such as disk, optical disk, etc.; and communication unit 19, such as network card, modem, wireless transceiver, etc. Communication unit 19 allows electronic device 10 to exchange information / data with other devices through computer networks such as the Internet and / or various telecommunications networks.

[0060] Processor 11 can be a variety of general-purpose and / or special-purpose processing components with processing and computing capabilities. Some examples of processor 11 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 11 performs the various methods and processes described above, such as reservoir recovery determination methods.

[0061] In some embodiments, the reservoir recovery determination method may be implemented as a computer program tangibly contained in a computer-readable storage medium, such as storage unit 18. In some embodiments, part or all of the computer program may be loaded and / or installed on electronic device 10 via ROM 12 and / or communication unit 19. When the computer program is loaded into RAM 13 and executed by processor 11, one or more steps of the reservoir recovery determination method described above may be performed. Alternatively, in other embodiments, processor 11 may be configured to perform the reservoir recovery determination method by any other suitable means (e.g., by means of firmware).

[0062] In particular, according to embodiments of the present invention, the processes described above with reference to the flowcharts 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 the methods shown in the flowcharts. In such embodiments, the computer program can be downloaded and installed from a network via communication unit 19, or installed from storage unit 18, or installed from ROM 12. When the computer program is executed by processor 11, it performs the functions defined in the methods of the embodiments of the present invention.

[0063] Various embodiments of the systems and techniques described above herein can be implemented in digital electronic circuit systems, integrated circuit systems, field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), application-specific standard products (ASSPs), systems-on-a-chip (SoCs), payload-programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various embodiments may include implementations in one or more computer programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which may be a dedicated or general-purpose programmable processor, capable of receiving data and instructions from a storage system, at least one input device, and at least one output device, and transmitting data and instructions to the storage system, the at least one input device, and the at least one output device.

[0064] Computer programs used to implement the methods of the present invention may be written in any combination of one or more programming languages. These computer programs may be provided to a processor of a general-purpose computer, a special-purpose computer, or other programmable data processing device, such that when executed by the processor, the computer programs cause the functions / operations specified in the flowcharts and / or block diagrams to be performed. The computer programs may be executed entirely on a machine, partially on a machine, or as a standalone software package, partially on a machine and partially on a remote machine, or entirely on a remote machine or server.

[0065] In the context of this invention, a computer-readable storage medium can be a tangible medium that may contain or store a computer program for use by or in conjunction with an instruction execution system, apparatus, or device. A computer-readable storage medium may include, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, apparatus, or devices, or any suitable combination thereof. Alternatively, a computer-readable storage medium may be a machine-readable signal medium. 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 thereof.

[0066] To provide interaction with a user, the systems and techniques described herein can be implemented on an electronic device having: a display device (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor) for displaying information to the user; and a keyboard and pointing device (e.g., a mouse or trackball) through which the user provides input to the electronic device. Other types of devices can also be used to provide interaction with the user; for example, feedback provided to the user can be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user can be received in any form (including sound input, voice input, or tactile input).

[0067] The systems and technologies described herein can be implemented in computing systems that include backend components (e.g., as data servers), or middleware components (e.g., application servers), or frontend components (e.g., user computers with graphical user interfaces or web browsers through which users can interact with implementations of the systems and technologies described herein), or any combination of such backend, middleware, or frontend components. The components of the system can be interconnected via digital data communication of any form or medium (e.g., communication networks). Examples of communication networks include local area networks (LANs), wide area networks (WANs), blockchain networks, and the Internet.

[0068] A computing system can include clients and servers. Clients and servers are generally located far apart and typically interact through communication networks. The client-server relationship is created by computer programs running on the respective computers and having a client-server relationship with each other. The server can be a cloud server, also known as a cloud computing server or cloud host, which is a hosting product within the cloud computing service system to address the shortcomings of traditional physical hosts and VPS services, such as high management difficulty and weak business scalability.

[0069] It should be understood that the various forms of processes shown above can be used, with steps reordered, added, or deleted. For example, the steps described in this invention can be executed in parallel, sequentially, or in different orders, as long as the desired result of the technical solution of this invention can be achieved, and this is not limited herein.

[0070] The specific embodiments described above do not constitute a limitation on the scope of protection of this invention. Those skilled in the art should understand that various modifications, combinations, sub-combinations, and substitutions can be made according to design requirements and other factors. Any modifications, equivalent substitutions, and improvements made within the spirit and principles of this invention should be included within the scope of protection of this invention.

Claims

1. A method for determining the degree of oil reservoir recovery, characterized in that, include: The first core test data corresponding to the first core sample and the second core test data corresponding to the second core sample of the target exploration area are obtained. The first core sample is obtained by vacuuming and pressurizing the target core sample with water, and the second core sample is obtained by oil-flooding water-saturated oil to establish bound water in the first core sample. Determine the target well distance in the target exploration area, and determine multiple displacement pressure gradients corresponding to different reservoir locations in the target exploration area, as well as the displacement range corresponding to each displacement pressure gradient; Based on the first core test data, the second core test data, the target well distance, multiple displacement pressure gradients, and the displacement range corresponding to each displacement pressure gradient, the oil reservoir recovery degree corresponding to the target exploration area is determined.

2. The method according to claim 1, characterized in that, The acquisition of first core test data corresponding to the first core sample and second core test data corresponding to the second core sample in the target exploration area includes: The original core samples from the target exploration area were washed with oil and dried to obtain the target core samples. The target core sample is vacuumed and pressurized with saturated water to generate a first core sample. The first core sample is then subjected to core T2 spectrum testing to obtain the first core test data corresponding to the first core sample. The first core sample was subjected to oil-driven water saturation to establish bound water, generating a second core sample. The second core sample was then subjected to core T2 spectrum testing to obtain the corresponding second core test data.

3. The method according to claim 1, characterized in that, The step of determining the target well distance in the target exploration area, and determining multiple displacement pressure gradients corresponding to different reservoir locations in the target exploration area and the displacement range corresponding to each displacement pressure gradient, includes: The distance between production wells and injection wells in the target exploration area is determined as the target well distance in the target exploration area, and the well connection line between the production wells and the injection wells is sampled to determine the location of multiple oil reservoirs in the target exploration area. Based on the target production data corresponding to the target exploration area and the multiple reservoir locations, the displacement pressure gradient corresponding to each reservoir location and the displacement range corresponding to the displacement pressure gradient are determined.

4. The method according to claim 1, characterized in that, The determination of the reservoir recovery degree corresponding to the target exploration area based on the first core test data, the second core test data, the target well-to-well distance, multiple displacement pressure gradients, and the displacement range corresponding to each displacement pressure gradient includes: Based on the first core test data, the second core test data, and multiple displacement pressure gradients, the degree of core extraction of the second core sample under each displacement pressure gradient is determined. Based on the target well distance, the displacement range corresponding to each displacement pressure gradient, and the core recovery degree, the reservoir recovery degree corresponding to the target exploration area is determined.

5. The method according to claim 4, characterized in that, The step of determining the core recovery extent of the second core sample under each displacement pressure gradient based on the first core test data, the second core test data, and multiple displacement pressure gradients includes: Based on the multiple displacement pressure gradients, the third core test data of the second core sample under each displacement pressure gradient is determined; Based on the first core test data, the second core test data, and the third core test data, the degree of core extraction of the second core sample under each displacement pressure gradient is determined.

6. The method according to claim 5, characterized in that, The determination of the third core test data of the second core sample under each displacement pressure gradient based on multiple displacement pressure gradients includes: Based on multiple displacement pressure gradients, water-drive oil centrifugation experiments were conducted on the second core samples under different displacement pressure gradients, and the core T2 spectrum was tested on the second core samples under different displacement pressure gradients after the experiments to determine the third core test data of the second core samples under each displacement pressure gradient.

7. The method according to claim 5, characterized in that, The step of determining the core recovery extent of the second core sample under each displacement pressure gradient based on the first core test data, the second core test data, and the third core test data includes: Based on the first core test data and the second core test data, the saturated water state corresponding to the first core sample and the saturated oil state corresponding to the second core sample are determined. Based on the saturated water state, the saturated oil state, and the third core test data, the degree of core recovery of the second core sample under each displacement pressure gradient is determined.

8. A device for determining the degree of oil reservoir recovery, characterized in that, include: The data acquisition module is used to acquire the first core test data corresponding to the first core sample and the second core test data corresponding to the second core sample in the target exploration area. The first core sample is obtained by vacuuming and pressurizing the target core sample with water, and the second core sample is obtained by saturating the first core sample with oil-driven water to establish bound water. The pressure gradient determination module is used to determine the target well distance in the target exploration area, and to determine multiple displacement pressure gradients corresponding to different reservoir locations in the target exploration area and the displacement range corresponding to each displacement pressure gradient. The recovery degree determination module is used to determine the reservoir recovery degree corresponding to the target exploration area based on the first core test data, the second core test data, the target well distance, multiple displacement pressure gradients, and the displacement range corresponding to each displacement pressure gradient.

9. An electronic device, characterized in that, The electronic device includes: At least one processor; and A memory communicatively connected to the at least one processor; wherein, The memory stores a computer program that can be executed by the at least one processor, the computer program being executed by the at least one processor to enable the at least one processor to perform the reservoir recovery determination method according to any one of claims 1-7.

10. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer instructions that, when executed by a processor, implement the method for determining the degree of oil recovery according to any one of claims 1-7.

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