Method, device and equipment for calculating production degree of water-drive reservoir and medium

Abstract

The invention discloses a water-drive reservoir production degree calculation method and device, equipment and a medium, and relates to the technical field of oil and gas field development. The method comprises the steps that an oil reservoir is divided into M well groups according to oil reservoir boundaries and oil-water well distribution characteristics; sequentially taking m from 1 to M, and establishing a rectangular coordinate system by taking one end point in the plurality of end points in the mth well group as an original point; the displacement pressure gradient of each point on the rectangular coordinate system in the mth well group is calculated; calculating the starting pressure gradient of each point on the rectangular coordinate system in the mth well group; according to the displacement pressure gradient and the starting pressure gradient of each point, whether each point is a using area or not is judged; adding the areas of all the use areas to obtain a total use area; and obtaining the oil reservoir production degree according to the total production area and the oil reservoir total area. According to the calculation method disclosed by the invention, the oil reservoir production degree is quantitatively evaluated, and the calculation method has important guiding significance in making development countermeasures for water-drive oil reservoirs and improving the oil reservoir development effect.

Description

Technical Field

[0001] The present application belongs to the technical field of oil and gas field development, and specifically relates to a method, device, equipment and medium for calculating the production degree of a water-driven oil reservoir. Background Art

[0002] At present, most of my country's oil fields have entered the high water content development stage, and the remaining oil is scattered in the reservoir, and it is increasingly difficult to further tap the potential of the remaining oil. Therefore, effectively estimating the production status of the reservoir plays a vital role in accurately evaluating the effect of oil field development. In order to solve this problem, there are many commonly used methods for evaluating the production status of the reservoir, which can be divided according to the profession, mainly including geological and seismic methods; reservoir engineering, well testing and numerical simulation methods; indoor experimental technology and process technology. Geological and seismic methods can provide information such as the structure and physical parameters of the formation, reservoir engineering, well testing and numerical simulation methods can provide real-time reservoir dynamic information and predict future production conditions, and indoor experimental technology and process technology can improve recovery and reduce costs through experimental analysis and process improvement.

[0003] These methods have their own advantages and disadvantages, but none of them can quantitatively evaluate the utilization degree of water-driven oil reservoirs, and have little reference value for formulating development strategies for water-driven oil reservoirs and improving the development effect of oil reservoirs. Summary of the invention

[0004] The present application aims to provide a method, device, equipment and medium for calculating the production degree of a water-driven oil reservoir, which at least solves the problem that the prior art cannot quantitatively evaluate the production degree of a water-driven oil reservoir.

[0005] In order to solve the above technical problems, this application is implemented as follows:

[0006] In a first aspect, an embodiment of the present application proposes a method for calculating the production degree of a water-driven oil reservoir, based on a water-driven oil reservoir of a well group, the method comprising:

[0007] According to the reservoir boundary and the distribution characteristics of oil and water wells, the reservoir is divided into M well groups, where M is an integer greater than 1;

[0008] Take m from 1 to M in sequence, take one of the endpoints in the mth well group as the origin, and establish a rectangular coordinate system;

[0009] Taking m from 1 to M in sequence, calculate the displacement pressure gradient of each point on the rectangular coordinate system in the m-th well group;

[0010] Taking m from 1 to M in sequence, calculate the starting pressure gradient of each point on the rectangular coordinate system in the m-th well group;

[0011] According to the displacement pressure gradient and the start-up pressure gradient of each point, determining whether each point is a producing area;

[0012] Add up the area of ​​each mobilized area to get the total mobilized area;

[0013] The producing degree of the oil reservoir is obtained according to the total producing area and the total area of ​​the oil reservoir.

[0014] Optionally, the reservoir is divided into M well groups according to the reservoir boundary and the distribution characteristics of oil and water wells, including:

[0015] Taking the water injection well as the center, connecting the oil production well connection line and the fault boundary, and dividing the reservoir into M well groups according to the reservoir boundary and the distribution characteristics of oil and water wells.

[0016] Optionally, the calculating the displacement pressure gradient of each point on the rectangular coordinate system in the m-th well group includes:

[0017] The displacement pressure gradient of each point on the rectangular coordinate system in the m-th well group is calculated according to the boundary conditions of different injection and production unit types, reservoir physical properties, well pattern and spacing, and injection and production intensity.

[0018] Optionally, the calculating the displacement pressure gradient of each point on the rectangular coordinate system in the m-th well group includes:

[0019] Take m from 1 to M in sequence, take one of the endpoints in the mth well group as the origin, and establish a rectangular coordinate system with 1 cm as the unit length;

[0020] The displacement pressure gradient formula is:

[0021]

[0022] Where: P (x,y) is the displacement pressure gradient at the midpoint (x, y) of the mth well group, μ o is the viscosity of crude oil, k is the absolute permeability of the reservoir at the midpoint (x, y) of the Mth well group, n is the total number of water injection wells and oil production wells in the mth well group, Q i is the flow rate of the ith water injection well or oil production well in the mth well group, h i is the reservoir thickness of the ith water injection well or oil production well in the mth well group, x i is the horizontal coordinate of the first water injection well or oil production well in the Mth well group, Y i is the ordinate of the Ith water injection well or oil production well in the mth well group, X is the abscissa of the midpoint (X, y) of the Mth well group, and Y is the ordinate of the midpoint (X, y) of the Mth well group.

[0023] Optionally, the calculation of the starting pressure gradient of each point on the rectangular coordinate system in the m-th well group is performed using the formula of the starting pressure gradient:

[0024] G (x,y) =0.005e -0.003k

[0025] Where: G (x,y) is the starting pressure gradient at the midpoint (x, y) of the mth well group, e is a natural constant, and k is the absolute permeability of the reservoir at the midpoint (x, y) of the mth well group.

[0026] Optionally, judging whether each point is a producing area according to the displacement pressure gradient and the start-up pressure gradient of each point includes:

[0027] comparing the magnitudes of the displacement pressure gradient and the start-up pressure gradient at each point;

[0028] The point where the displacement pressure gradient is greater than the starting pressure gradient is determined as the producing area.

[0029] Optionally, obtaining the oil reservoir production degree according to the total producing area and the total oil reservoir area includes:

[0030] The total producing area is divided by the total area of ​​the oil reservoir to obtain the producing degree of the oil reservoir.

[0031] In a second aspect, an embodiment of the present application provides a device for calculating the production degree of a water-driven oil reservoir, based on a water-driven oil reservoir of a well group, the device comprising:

[0032] A well group division module, used for dividing the oil reservoir into M well groups according to the oil reservoir boundary and the distribution characteristics of oil and water wells, where M is an integer greater than 1;

[0033] A coordinate system establishment module is used to sequentially take m from 1 to M and establish a rectangular coordinate system with one of the multiple endpoints in the mth well group as the origin;

[0034] The first calculation module is used to sequentially take m from 1 to M and calculate the displacement pressure gradient of each point on the rectangular coordinate system in the m-th well group;

[0035] The second calculation module is used to sequentially take m from 1 to M and calculate the starting pressure gradient of each point on the rectangular coordinate system in the m-th well group;

[0036] A judgment module, used for judging whether each point is a producing area according to the displacement pressure gradient and the starting pressure gradient of each point;

[0037] The third calculation module is used to add up the area of ​​each mobilized area to obtain the total mobilized area;

[0038] The fourth calculation module is used to obtain the oil reservoir production degree according to the total production area and the total area of ​​the oil reservoir.

[0039] Optionally, the well group division module includes:

[0040] The first division submodule is used to divide the reservoir into M well groups with the water injection well as the center, connected by the oil production well connection line and the fault boundary, according to the reservoir boundary and the distribution characteristics of oil and water wells.

[0041] Optionally, the first calculation module includes:

[0042] The first calculation submodule is used to calculate the displacement pressure gradient of each point on the rectangular coordinate system in the mth well group according to the boundary conditions of different injection and production unit types, reservoir physical properties, well pattern and spacing, and injection and production intensity.

[0043] Optionally, the judging module includes:

[0044] A comparison submodule, used for comparing the magnitude of the displacement pressure gradient and the start-up pressure gradient of each point;

[0045] The judgment submodule is used to judge the point where the displacement pressure gradient is greater than the starting pressure gradient as the producing area.

[0046] Optionally, the fourth calculation module includes:

[0047] The oil reservoir production degree calculation submodule is used to obtain the oil reservoir production degree by dividing the total production area by the total area of ​​the oil reservoir.

[0048] In a third aspect, an embodiment of the present application proposes an electronic device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the computer program, when executed by the processor, implements a method for calculating the degree of utilization of a water-driven oil reservoir as described in any one of the first aspects of the present application.

[0049] In a fourth aspect, an embodiment of the present application provides a readable storage medium having a computer program stored thereon, and when the computer program is executed by a processor, the method for calculating the degree of utilization of a water-driven oil reservoir as described in any one of the first aspects of the present application is implemented.

[0050] The technical solution provided by the embodiments of the present application may have the following beneficial effects:

[0051] Water-drive reservoir development based on well groups is the main technology for reservoir development. Evaluating the degree of utilization of water-drive reservoirs and clarifying the scope of reservoir utilization can formulate targeted measures to tap the potential of remaining oil, which has important guiding significance for improving the effect of reservoir development. In the embodiments of the present application, the reservoir is divided into several well groups according to the reservoir boundary and the distribution characteristics of oil and water wells; for different types of well groups, the utilization area of ​​the water-drive reservoir in the well group is calculated by comparing the displacement pressure gradient and the start-up pressure gradient; and the utilization degree of the reservoir is obtained based on the area of ​​all the utilization areas and the total area of ​​the reservoir, thereby forming a method for calculating the fine utilization degree of water-drive reservoirs based on well groups. The calculation method provided in the embodiments of the present application has important guiding significance for formulating development strategies for water-drive reservoirs.

[0052] Additional aspects and advantages of the present application will be given in part in the description below, and in part will become apparent from the description below, or will be learned through the practice of the present application. BRIEF DESCRIPTION OF THE DRAWINGS

[0053] The above and / or additional aspects and advantages of the present application will become apparent and easily understood from the description of the embodiments in conjunction with the following drawings, in which:

[0054] Figure 1 This is a flow chart of a method for calculating the production degree of a water-driven oil reservoir based on a well group provided in one embodiment of the present application;

[0055] Figure 2 It is a well group division plan diagram provided by an embodiment of the present application;

[0056] Figure 3 It is a water drive reservoir production degree distribution map based on a well group provided in one embodiment of the present application;

[0057] Figure 4 This is a module block diagram of a water drive reservoir production degree calculation device provided by an embodiment of the present application;

[0058] Figure 5 It is a schematic diagram of an electronic device provided by an embodiment of the present application. DETAILED DESCRIPTION

[0059] The embodiments of the present application will be described in detail below, and examples of the embodiments are shown in the accompanying drawings, wherein the same or similar reference numerals throughout represent the same or similar elements or elements having the same or similar functions. The embodiments described below with reference to the accompanying drawings are exemplary and are only used to explain the present application, and should not be construed as limitations on the present application. Based on the embodiments in the present application, all other embodiments obtained by ordinary technicians in the field without making creative work are within the scope of protection of the present application.

[0060] It should be noted that the illustrations provided in the following embodiments are only schematic illustrations of the basic concept of the present application, and thus the drawings only show components related to the present application rather than being drawn according to the number, shape and size of components in actual implementation. In actual implementation, the type, quantity and proportion of each component may be changed at will, and the component layout may also be more complicated.

[0061] refer to Figure 1 , Figure 1 1 is a flow chart of a method for calculating the utilization degree of a water-driven oil reservoir based on a well group provided in one embodiment of the present application. Figure 1 As shown, the method for calculating the production degree of a water-driven oil reservoir provided in this embodiment may include the following steps:

[0062] Step S101: Divide the oil reservoir into M well groups according to the reservoir boundary and oil and water well distribution characteristics, where M is an integer greater than 1.

[0063] In this embodiment, the reservoir can be subdivided into multiple well groups based on the reservoir boundary and oil and water well distribution characteristics, and can also be combined with specific characteristics of the reservoir such as fault distribution, well network, and reservoir boundary. This process of dividing well groups requires the comprehensive use of various geological information and engineering data to achieve the best division results. Fault boundaries are an important reference for dividing well groups. Faults are fracture surfaces formed in the crust due to ground stress. They may change the shape and size of the reservoir and may also affect the migration and accumulation of oil and gas. Therefore, it is necessary to consider the distribution and properties of faults and incorporate them into the process of well group division.

[0064] Step S102: sequentially select m from 1 to M, and establish a rectangular coordinate system with one of the multiple endpoints in the mth well group as the origin.

[0065] In this embodiment, after the well groups are divided, in order to facilitate calculation, a rectangular coordinate system needs to be established in each well group. First, an endpoint is selected as the origin in each well group. This endpoint can be any endpoint of the well group, because it will not affect the subsequent establishment of the rectangular coordinate system and the calculation process. However, considering the convenience of calculation, the endpoint in the lower left corner is generally selected as the origin, so that the other points in the well group are in the first quadrant of the rectangular coordinate system.

[0066] Step S103: taking m from 1 to M in sequence, and calculating the displacement pressure gradient of each point on the rectangular coordinate system in the mth well group.

[0067] In this embodiment, after establishing a rectangular coordinate system with one of the endpoints of each well group as the origin, it is necessary to calculate the displacement pressure gradient of each point on the rectangular coordinate system in each well group. The displacement pressure gradient refers to the change in displacement pressure per unit distance, which is one of the important parameters in reservoir development.

[0068] Step S104: taking m from 1 to M in sequence, and calculating the starting pressure gradient of each point on the rectangular coordinate system in the mth well group.

[0069] In this embodiment, after establishing a rectangular coordinate system with one of the endpoints of each well group as the origin, the next step is to calculate the starting pressure gradient of each point on the rectangular coordinate system in each well group. The starting pressure gradient refers to the change in starting pressure per unit distance, which is another important parameter in reservoir development.

[0070] Step S105: judging whether each point is a producing area according to the displacement pressure gradient and the start-up pressure gradient of each point.

[0071] In this embodiment, according to the displacement pressure gradient and the start-up pressure gradient of each point on the rectangular coordinate system in each well group, it can be determined whether these points belong to the producing area.

[0072] First, a judgment standard needs to be set. For example, the relative size of the displacement pressure gradient and the start-up pressure gradient at the same point can be used for judgment; or the threshold of the displacement pressure gradient and the start-up pressure gradient can be set, and this threshold can be selected according to the actual situation of the reservoir and development needs. Then, the displacement pressure gradient and the start-up pressure gradient of each point are compared for judgment, or compared with the set threshold.

[0073] Step S106: Add the area of ​​each mobilized area to obtain the total mobilized area.

[0074] In this embodiment, after the producing area in each well group is determined, the area of ​​each producing area needs to be added together to obtain the total producing area.

[0075] Step S107: Obtaining the oil reservoir producing degree according to the total producing area and the total oil reservoir area.

[0076] In this embodiment, after the total producing area is calculated, the producing degree of the oil reservoir can be obtained according to the ratio of the total producing area to the total area of ​​the oil reservoir or other more preferred calculation methods.

[0077] Specifically, the method provided in this embodiment divides the water-drive reservoir into multiple well groups, establishes a rectangular coordinate system, and calculates the displacement pressure gradient and the start-up pressure gradient to evaluate the utilization area of ​​the water-drive reservoir. The utilization degree of the water-drive reservoir is evaluated according to the ratio of the total area of ​​the utilization area to the total area of ​​the water-drive reservoir, so as to formulate a more scientific and reasonable development and management plan for the water-drive reservoir to achieve the maximum recovery rate of the water-drive reservoir.

[0078] In combination with the above embodiments, in one implementation manner, the oil reservoir is divided into M well groups according to the oil reservoir boundary and the oil and water well distribution characteristics, including:

[0079] Taking the water injection well as the center, connecting the oil production well connection line and the fault boundary, and dividing the reservoir into M well groups according to the reservoir boundary and the distribution characteristics of oil and water wells.

[0080] In this embodiment, the location of the water injection well needs to be clarified. The water injection well is a key device for injecting water into the oil reservoir, and its location is usually carefully selected to maximize the recovery rate. Then, the division of the well group is carried out with the water injection well as the center.

[0081] Specifically, Figure 2 This is a well group division plan diagram provided by an embodiment of the present application. Figure 2 As shown, with the water injection well as the center and connected by the oil production well connection line and the fault boundary, the reservoir is divided into 6 well groups numbered 1-6 according to the reservoir boundary and the distribution characteristics of oil and water wells.

[0082] In combination with the above embodiments, in one implementation manner, the calculation of the displacement pressure gradient of each point on the rectangular coordinate system in the m-th well group includes:

[0083] The displacement pressure gradient of each point on the rectangular coordinate system in the m-th well group is calculated according to the boundary conditions of different injection and production unit types, reservoir physical properties, well pattern and spacing, and injection and production intensity.

[0084] In this embodiment, the displacement pressure gradient can be calculated by determining the corresponding boundary conditions, reservoir properties, well spacing and injection-production intensity according to the injection-production unit type of each well group. These parameters can be obtained by actual measurement or numerical simulation methods, depending on the actual situation of the reservoir and development requirements.

[0085] Specifically, the connectivity of each reservoir point in the well group is determined, taking into account the boundary conditions of the well group. If the connectivity between two wells is poor, the displacement pressure gradient between them may be limited.

[0086] Specifically, the calculation method of displacement pressure gradient is determined according to the reservoir physical properties and well spacing. For example, if the reservoir is homogeneous, a simple pressure difference method can be used to calculate the displacement pressure gradient; if the reservoir is heterogeneous, a more complex numerical simulation method may be required to calculate the displacement pressure gradient.

[0087] Specifically, the variation law of displacement pressure gradient is determined according to the injection-production intensity. Generally speaking, the greater the injection-production intensity, the greater the displacement pressure gradient. Therefore, when determining the displacement pressure gradient, the variation of injection-production intensity needs to be considered.

[0088] In combination with the above embodiments, in one implementation manner, the calculation of the displacement pressure gradient of each point on the rectangular coordinate system in the m-th well group includes:

[0089] Take m from 1 to M in sequence, take one of the endpoints in the mth well group as the origin, and establish a rectangular coordinate system with 1 cm as the unit length;

[0090] The displacement pressure gradient formula is:

[0091]

[0092] Where: P (x,y) is the displacement pressure gradient at the midpoint (x, y) of the mth well group, μ o is the viscosity of crude oil, k is the absolute permeability of the reservoir at the midpoint (x, y) of the mth well group, n is the total number of water injection wells and oil production wells in the mth well group, Q i is the flow rate of the ith water injection well or oil production well in the mth well group, h i is the reservoir thickness of the ith water injection well or oil production well in the mth well group, x i is the horizontal coordinate of the ith water injection well or oil production well in the mth well group, y i is the ordinate of the ith injection well or oil production well in the mth well group, x is the abscissa of the midpoint (x, y) of the mth well group, and y is the ordinate of the midpoint (x, y) of the mth well group.

[0093] In this embodiment, for the convenience of calculation, after establishing a coordinate system with one of the endpoints of each well group, it is necessary to set the unit length. For example, 1 cm is used as the unit length. Of course, the unit length can also be increased or decreased. It is understandable that the larger the unit length, the greater the error, and the smaller the unit length, the more accurate the value obtained.

[0094] Optionally, the following table is Figure 2 Water injection wells, oil production wells, reservoirs and fluid parameters in well group 1.

[0095]

[0096] Specifically, take the point (400, 200) in well group 1 as an example:

[0097] Calculate P (400,200) =8.20×10 -5 MPa / cm = 8.20 × 10 -3 MPa / m.

[0098] By combining the parameters of each point and repeating the above operation, the displacement pressure gradient of all points in the well group 1 can be calculated, which will not be described in detail in this application.

[0099] In combination with the above embodiments, in one implementation manner, the starting pressure gradient of each point on the rectangular coordinate system in the m-th well group is calculated, and the starting pressure gradient formula is:

[0100] G (x,y) =0.005e -0.003k

[0101] Where: G (x,y) is the starting pressure gradient at the midpoint (x, y) of the mth well group, e is a natural constant, and k is the absolute permeability of the reservoir at the midpoint (x, y) of the mth well group.

[0102] Specifically, Figure 2 Take the point (400, 200) in well group 1 as an example:

[0103] Calculate G (400,200) =3.70×10 -3 MPa / m.

[0104] By combining the parameters of each point and repeating the above operation, the starting pressure gradient of all points in the well group 1 can be calculated, which will not be described in detail in this application.

[0105] In combination with the above embodiments, in one implementation manner, judging whether each point is a producing area according to the displacement pressure gradient and the start-up pressure gradient of each point includes:

[0106] comparing the magnitudes of the displacement pressure gradient and the start-up pressure gradient at each point;

[0107] The point where the displacement pressure gradient is greater than the starting pressure gradient is determined as the producing area.

[0108] Specifically, Figure 2 Take the point (400, 200) in well group 1 as an example:

[0109] Because P (400,200) =8.20×10 -3 MPa / m is greater than G (400,200) =3.70×10 -3 MPa / m, so the point (400, 200) is the mobilization area.

[0110] By repeating the above operations, the utilization status of all points in the well group 1 can be compared and determined, which will not be described in detail in this application.

[0111] Specifically, Figure 3 This is a water drive reservoir production degree distribution map based on a well group provided in one embodiment of the present application. Figure 3 As shown, after comparing the production conditions of all points in the well group in the water drive reservoir, the following can be obtained: Figure 3The distribution diagram shown in the figure is used, and the next operation is performed based on the utilization situation and the distribution diagram.

[0112] In combination with the above embodiments, in one implementation manner, obtaining the oil reservoir production degree according to the total production area and the total oil reservoir area includes:

[0113] The total producing area is divided by the total area of ​​the oil reservoir to obtain the producing degree of the oil reservoir.

[0114] In this embodiment, after the total producing area is calculated, the producing degree of the oil reservoir can be obtained by dividing the total producing area by the total area of ​​the oil reservoir.

[0115] Specifically, as shown in the following table, the following table is based on Figure 2 The utilized area of ​​each well group and the total area of ​​the well groups are calculated.

[0116]

[0117] Specifically, the total produced area can be obtained by adding up the produced areas of each well group; the total area of ​​the reservoir can be obtained by adding up the total areas of each well group; the total produced area divided by the total area of ​​the reservoir can be obtained to determine the degree of reservoir production.

[0118] Figure 4 is a block diagram of a water-drive oil reservoir production degree calculation device provided by an embodiment of the present application. Based on the same inventive concept, another embodiment of the present application provides a water-drive oil reservoir production degree calculation device, based on a water-drive oil reservoir of a well group, such as Figure 4 As shown, the device comprises:

[0119] A well group division module, used for dividing the oil reservoir into M well groups according to the oil reservoir boundary and the distribution characteristics of oil and water wells, where M is an integer greater than 1;

[0120] A coordinate system establishment module is used to sequentially take m from 1 to M and establish a rectangular coordinate system with one of the multiple endpoints in the mth well group as the origin;

[0121] The first calculation module is used to sequentially take m from 1 to M and calculate the displacement pressure gradient of each point on the rectangular coordinate system in the m-th well group;

[0122] The second calculation module is used to sequentially take m from 1 to M and calculate the starting pressure gradient of each point on the rectangular coordinate system in the m-th well group;

[0123] A judgment module, used for judging whether each point is a producing area according to the displacement pressure gradient and the starting pressure gradient of each point;

[0124] The third calculation module is used to add up the area of ​​each mobilized area to obtain the total mobilized area;

[0125] The fourth calculation module is used to obtain the oil reservoir production degree according to the total production area and the total area of ​​the oil reservoir.

[0126] Optionally, the well group division module includes:

[0127] The first division submodule is used to divide the reservoir into M well groups with the water injection well as the center, connected by the oil production well connection line and the fault boundary, according to the reservoir boundary and the distribution characteristics of oil and water wells.

[0128] Optionally, the first calculation module includes:

[0129] The first calculation submodule is used to calculate the displacement pressure gradient of each point on the rectangular coordinate system in the mth well group according to the boundary conditions of different injection and production unit types, reservoir physical properties, well pattern and spacing, and injection and production intensity.

[0130] Optionally, the judging module includes:

[0131] A comparison submodule, used for comparing the magnitude of the displacement pressure gradient and the start-up pressure gradient of each point;

[0132] The judgment submodule is used to judge the point where the displacement pressure gradient is greater than the starting pressure gradient as the producing area.

[0133] Optionally, the fourth calculation module includes:

[0134] The oil reservoir production degree calculation submodule is used to obtain the oil reservoir production degree by dividing the total production area by the total area of ​​the oil reservoir.

[0135] Based on the same inventive concept, another embodiment of the present application provides an electronic device, including a memory, a processor and a computer program stored on the memory, wherein the processor executes the computer program to implement the method for calculating the degree of utilization of a water-driven oil reservoir as described in any of the above embodiments of the present application.

[0136] Specifically, the present application also provides an electronic device, referring to Figure 5 , Figure 5 is a schematic diagram of an electronic device provided by an embodiment of the present application. Figure 5 As shown, the electronic device 100 includes: a memory 110 and a processor 120. The memory 110 and the processor 120 are connected via a bus communication. A computer program is stored in the memory 110. The computer program can be run on the processor 120 to implement the method for calculating the degree of utilization of a water-driven oil reservoir described in any of the above embodiments of the present invention.

[0137] Based on the same inventive concept, another embodiment of the present application provides a readable storage medium on which a computer program / instruction is stored. When the computer program / instruction is executed by a processor, the method for calculating the degree of utilization of a water-driven oil reservoir described in any of the above embodiments of the present application is implemented.

[0138] The various embodiments in this specification are described in a progressive manner, and each embodiment focuses on the differences from other embodiments. The same or similar parts between the various embodiments can be referenced to each other.

[0139] As for the device embodiment, since it is basically similar to the method embodiment, the description is relatively simple, and the relevant parts can be referred to the partial description of the method embodiment.

[0140] In the description of this specification, the description with reference to the terms "one embodiment", "some embodiments", "illustrative embodiments", "examples", "specific examples", or "some examples" means that the specific features, structures, materials, or characteristics described in conjunction with the embodiment or example are included in at least one embodiment or example of the present application. In this specification, the schematic representation of the above terms does not necessarily refer to the same embodiment or example. Moreover, the specific features, structures, materials, or characteristics described may be combined in any one or more embodiments or examples in a suitable manner.

[0141] Those skilled in the art should understand that the embodiments of the present application can be provided as methods, devices, electronic devices, storage media or computer program products. Therefore, the embodiments of the present application can take the form of a complete hardware embodiment, a complete software embodiment, or an embodiment combining software and hardware. Moreover, the embodiments of the present application can take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0142] Although the embodiments of the present application have been shown and described, those skilled in the art will appreciate that various changes, modifications, substitutions and variations may be made to the embodiments without departing from the principles and spirit of the present application, and that the scope of the present application is defined by the claims and their equivalents.

[0143] Finally, it should be noted that, in this article, relational terms such as first and second, etc. are only used to distinguish one entity or operation from another entity or operation, and do not necessarily require or imply any such actual relationship or order between these entities or operations. Moreover, the terms "include", "comprise" or any other variants thereof are intended to cover non-exclusive inclusion, so that a process, method, article or terminal device including a series of elements includes not only those elements, but also other elements not explicitly listed, or also includes elements inherent to such process, method, article or terminal device. In the absence of further restrictions, the elements defined by the sentence "comprise a ..." do not exclude the existence of other identical elements in the process, method, article or terminal device including the elements.

[0144] The above is a detailed introduction to a method, device, equipment and medium for calculating the utilization degree of a water-driven oil reservoir provided by the present application. Specific examples are used in this article to illustrate the principle and implementation method of the present application. The description of the above embodiments is only used to help understand the method and its core idea of ​​the present application. At the same time, for those of ordinary skill in the art, according to the idea of ​​the present application, there will be changes in the specific implementation method and application scope. In summary, the content of this specification should not be understood as a limitation on the present application. The above embodiments are only preferred embodiments cited to fully illustrate the present application, and the protection scope of the present application is not limited thereto. Equivalent substitutions or changes made by those skilled in the art on the basis of the present application are all within the protection scope of the present application.

Claims

1. A method for calculating the production degree of a water-driven oil reservoir, characterized in that: Based on a water-driven oil reservoir of a well group, the method comprises: According to the reservoir boundary and the distribution characteristics of oil and water wells, the reservoir is divided into M well groups, where M is an integer greater than 1; Take m from 1 to M in sequence, take one of the endpoints in the mth well group as the origin, and establish a rectangular coordinate system; Taking m from 1 to M in sequence, calculate the displacement pressure gradient of each point on the rectangular coordinate system in the m-th well group; Taking m from 1 to M in sequence, calculate the starting pressure gradient of each point on the rectangular coordinate system in the m-th well group; According to the displacement pressure gradient and the start-up pressure gradient of each point, determining whether each point is a producing area; Add up the area of ​​each mobilized area to get the total mobilized area; The producing degree of the oil reservoir is obtained according to the total producing area and the total area of ​​the oil reservoir.

2. The method according to claim 1, characterized in that According to the reservoir boundary and the distribution characteristics of oil and water wells, the reservoir is divided into M well groups, including: Taking the water injection well as the center, connecting the oil production well connection line and the fault boundary, and dividing the reservoir into M well groups according to the reservoir boundary and the distribution characteristics of oil and water wells.

3. The method according to claim 1, characterized in that The calculating of the displacement pressure gradient of each point on the rectangular coordinate system in the m-th well group comprises: The displacement pressure gradient of each point on the rectangular coordinate system in the m-th well group is calculated according to the boundary conditions of different injection and production unit types, reservoir physical properties, well pattern and spacing, and injection and production intensity.

4. The method according to claim 1, characterized in that The calculating of the displacement pressure gradient of each point on the rectangular coordinate system in the m-th well group comprises: Take m from 1 to M in sequence, take one of the endpoints in the mth well group as the origin, and establish a rectangular coordinate system with 1 cm as the unit length; The displacement pressure gradient formula is: Where: P (x，y) is the displacement pressure gradient at the midpoint (x, y) of the mth well group, μ o is the viscosity of crude oil, k is the absolute permeability of the reservoir at the midpoint (x, y) of the mth well group, n is the total number of water injection wells and oil production wells in the mth well group, Q i is the flow rate of the ith water injection well or oil production well in the mth well group, h i is the reservoir thickness of the ith water injection well or oil production well in the mth well group, x i is the horizontal coordinate of the ith water injection well or oil production well in the mth well group, y i is the ordinate of the ith water injection well or oil production well in the mth well group, x is the abscissa of the midpoint (x, y) of the mth well group, and y is the ordinate of the midpoint (x, y) of the mth well group.

5. The method according to claim 1, characterized in that The starting pressure gradient of each point on the rectangular coordinate system in the m-th well group is calculated, and the starting pressure gradient formula is: G (x，y) =0.005e -0.003k Where: G (x，y) is the starting pressure gradient at the midpoint (x, y) of the mth well group, e is a natural constant, and k is the absolute permeability of the reservoir at the midpoint (x, y) of the mth well group.

6. The method according to claim 1, characterized in that The step of judging whether each point is a producing area according to the displacement pressure gradient and the start-up pressure gradient of each point includes: comparing the magnitudes of the displacement pressure gradient and the start-up pressure gradient at each point; The point where the displacement pressure gradient is greater than the starting pressure gradient is determined as the producing area.

7. The method according to claim 1, characterized in that The step of obtaining the oil reservoir production degree according to the total production area and the total oil reservoir area includes: The total producing area is divided by the total area of ​​the oil reservoir to obtain the producing degree of the oil reservoir.

8. A water-driven oil reservoir production degree calculation device, characterized in that: Based on a water-driven oil reservoir of a well group, the device comprises: A well group division module, used for dividing the oil reservoir into M well groups according to the oil reservoir boundary and the distribution characteristics of oil and water wells, where M is an integer greater than 1; A coordinate system establishment module is used to sequentially take m from 1 to M and establish a rectangular coordinate system with one of the multiple endpoints in the mth well group as the origin; The first calculation module is used to sequentially take m from 1 to M and calculate the displacement pressure gradient of each point on the rectangular coordinate system in the m-th well group; The second calculation module is used to sequentially take m from 1 to M and calculate the starting pressure gradient of each point on the rectangular coordinate system in the m-th well group; A judgment module, used for judging whether each point is a producing area according to the displacement pressure gradient and the starting pressure gradient of each point; The third calculation module is used to add up the area of ​​each mobilized area to obtain the total mobilized area; The fourth calculation module is used to obtain the oil reservoir production degree according to the total production area and the total area of ​​the oil reservoir.

9. An electronic device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein: When the computer program is executed by the processor, the method for calculating the production degree of a water-driven oil reservoir as claimed in any one of claims 1 to 7 is implemented.

10. A readable storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by a processor, the method for calculating the production degree of a water-driven oil reservoir as claimed in any one of claims 1 to 7 is implemented.

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