Oil reservoir water injection treatment method and device and electronic equipment

Abstract

The invention discloses an oil reservoir water injection treatment method and device and electronic equipment. The method comprises the steps that N water injection wells included in a target oil reservoir and M oil production wells corresponding to the N water injection wells are obtained, N is an integer larger than 0, and M is an integer larger than N; determining X water injection wells from the N water injection wells, and determining oil production wells corresponding to the X water injection wells from the M oil production wells to obtain Y oil production wells; accumulated water injection rates corresponding to the N water injection wells and accumulated water yields corresponding to the Y oil production wells are obtained; and on the basis of the accumulated water injection rates corresponding to the N water injection wells and the accumulated water production rates corresponding to the Y oil production wells, the water injection effective utilization rate of the target oil reservoir is determined. According to the invention, the technical problem of low water injection utilization condition evaluation accuracy caused by incomplete consideration factors of an oil reservoir water injection treatment method in related technologies is solved.

Description

Technical Field

[0001] The present invention relates to the field of oil and gas field development, and in particular to an oil reservoir water injection treatment method, device and electronic equipment. Background Art

[0002] With the change of oil development objects, the development methods have also shown diversified characteristics, but water injection development is still the most economical and effective development method. For water injection development reservoirs, the injected water can be divided into two parts. One part of the injected water is used to displace the crude oil in the oil layer or make up for the formation deficit and maintain the formation energy, which is called effective water injection; the other part of the injected water is affected by reservoir characteristics, development technology policies and management factors, forming an invalid cycle in the formation or being produced with the crude oil, which is called invalid water injection. With the extension of development time, the law of groundwater drive becomes more and more complex, micro-fractures are opened, profile contradictions are aggravated, invalid water injection is increasing, and the effectiveness of water injection continues to decline. Therefore, the calculation of the effective utilization rate of water injection that is fast, accurate, real-time, effective and highly operational is crucial to master the utilization status of oil reservoir water injection, evaluate the water injection effect, and guide optimization and adjustment. However, the factors considered in the relevant technology of oil reservoir water injection treatment method are not comprehensive, resulting in the problem of low accuracy in the evaluation of water injection utilization.

[0003] To address the above-mentioned problems, no effective solution has been proposed yet. Summary of the invention

[0004] The embodiments of the present invention provide a reservoir water injection treatment method, device and electronic equipment to at least solve the technical problem that the reservoir water injection treatment method in the related art does not consider all factors, resulting in low accuracy in water injection utilization status evaluation.

[0005] According to one aspect of an embodiment of the present invention, a method for oil reservoir water injection processing is provided, comprising: obtaining N water injection wells included in a target oil reservoir, and M oil production wells corresponding to the N water injection wells, wherein N is an integer greater than 0, and M is an integer greater than N; determining X water injection wells from the N water injection wells, and determining the oil production wells corresponding to the X water injection wells from the M oil production wells, to obtain Y oil production wells, wherein X is an integer greater than 0 and less than N, and Y is an integer greater than X and less than M; obtaining the cumulative water injection volume corresponding to the N water injection wells, and the cumulative water production volume corresponding to the Y oil production wells; determining the effective utilization rate of water injection of the target oil reservoir based on the cumulative water injection volume corresponding to the N water injection wells, and the cumulative water production volume corresponding to the Y oil production wells.

[0006] According to another aspect of an embodiment of the present invention, there is further provided an oil reservoir water injection processing device, comprising: a first acquisition module, used to acquire N water injection wells included in a target oil reservoir, and M oil production wells corresponding to the N water injection wells, wherein N is an integer greater than 0, and M is an integer greater than N; a first determination module, used to determine X water injection wells from the N water injection wells, and to determine the oil production wells corresponding to the X water injection wells from the M oil production wells, to obtain Y oil production wells, wherein X is an integer greater than 0 and less than N, and Y is an integer greater than X and less than M; a second acquisition module, used to acquire the cumulative water injection volume corresponding to the N water injection wells, and the cumulative water production volume corresponding to the Y oil production wells; a second determination module, used to determine the effective utilization rate of water injection of the target oil reservoir based on the cumulative water injection volume corresponding to the N water injection wells, and the cumulative water production volume corresponding to the Y oil production wells.

[0007] According to another aspect of an embodiment of the present invention, there is also provided an electronic device, comprising one or more processors and a memory, wherein the memory is used to store one or more programs, wherein when the one or more programs are executed by the one or more processors, the one or more processors implement any one of the reservoir water injection treatment methods.

[0008] In an embodiment of the present invention, by obtaining N water injection wells included in the target oil reservoir, and M oil production wells corresponding to the N water injection wells, wherein N is an integer greater than 0, and M is an integer greater than N; determining X water injection wells from the N water injection wells, and determining the oil production wells corresponding to the X water injection wells from the M oil production wells, to obtain Y oil production wells, wherein X is an integer greater than 0 and less than N, and Y is an integer greater than X and less than M; obtaining the cumulative water injection volume corresponding to the N water injection wells, and the cumulative water production volume corresponding to the Y oil production wells. Based on the cumulative water injection volume corresponding to the N water injection wells and the cumulative water production volume corresponding to the Y oil production wells, the effective utilization rate of water injection of the target oil reservoir is determined, and the purpose of accurately determining the effective utilization rate of water injection of the target oil reservoir is achieved based on the ratio of the water injection volume required for the pressure to be restored to the current level under homogeneous conditions and the actual cumulative water injection volume, thereby achieving the technical effect of improving the accuracy of the effective utilization rate of water injection, and further solving the technical problem of low accuracy in the evaluation of water injection utilization status caused by incomplete consideration of factors in the oil reservoir water injection treatment method in the related technology. BRIEF DESCRIPTION OF THE DRAWINGS

[0009] The drawings described herein are used to provide a further understanding of the present invention and constitute a part of this application. The exemplary embodiments of the present invention and their descriptions are used to explain the present invention and do not constitute an improper limitation of the present invention. In the drawings:

[0010] Figure 1is a flow chart of a reservoir water injection treatment method according to an embodiment of the present invention;

[0011] Figure 2 is a schematic diagram of an optional water drive front according to an embodiment of the present invention;

[0012] Figure 3 is a schematic diagram of an optional water content and water content rise rate curve according to an embodiment of the present invention;

[0013] Figure 4 is a schematic diagram of an optional water injection unit area according to an embodiment of the present invention;

[0014] Figure 5 is a schematic diagram of another optional water drive front according to an embodiment of the present invention;

[0015] Figure 6 is a schematic diagram of an optional inspection well deployment according to an embodiment of the present invention;

[0016] Figure 7a is a schematic diagram of an optional well test production curve according to an embodiment of the present invention;

[0017] Figure 7b is a schematic diagram of another optional well test production curve according to an embodiment of the present invention;

[0018] Figure 7c is a schematic diagram of another optional well test production curve according to an embodiment of the present invention;

[0019] Figure 8 is a schematic diagram of an oil reservoir water injection treatment device according to an embodiment of the present invention;

[0020] Fig. 9 is a schematic diagram of an electronic device provided according to an embodiment of the present application. DETAILED DESCRIPTION

[0021] In order to enable those skilled in the art to better understand the scheme of the present invention, the technical scheme in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work should fall within the scope of protection of the present invention.

[0022] It should be noted that the terms "first", "second", etc. in the specification and claims of the present invention and the above-mentioned drawings are used to distinguish similar objects, and are not necessarily used to describe a specific order or sequence. It should be understood that the data used in this way can be interchangeable where appropriate, so that the embodiments of the present invention described herein can be implemented in an order other than those illustrated or described herein. In addition, the terms "including" and "having" and any variations thereof are intended to cover non-exclusive inclusions. For example, a process, method, system, product or device that includes a series of steps or units is not necessarily limited to those steps or units clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or devices.

[0023] According to an embodiment of the present invention, a method embodiment of oil reservoir water injection treatment is provided. It should be noted that the steps shown in the flowchart of the accompanying drawings can be executed in a computer system such as a set of computer executable instructions, and although a logical order is shown in the flowchart, in some cases, the steps shown or described can be executed in an order different from that shown here.

[0024] Figure 1 : is a flow chart of a reservoir water injection treatment method according to an embodiment of the present invention. Figure 1 As shown, the method comprises the following steps:

[0025] Step S102, obtaining N water injection wells included in the target oil reservoir, and M oil production wells corresponding to the N water injection wells, wherein N is an integer greater than 0, and M is an integer greater than N.

[0026] Optionally, in oil and gas production, water injection wells and oil production wells are interrelated. Water injection wells inject water into underground oil layers to increase the oil layer pressure and drive the oil in the reservoir to flow to the oil production wells. Oil production wells achieve oil and gas production by extracting oil from the oil wells. One water injection well usually corresponds to multiple oil production wells (generally one water injection well corresponds to 3 oil production wells). Water injection wells and oil production wells work together to increase reservoir pressure through water injection, drive oil to flow to oil production wells, and improve production efficiency.

[0027] Step S104, determining X water injection wells from the N water injection wells, and determining the oil production wells corresponding to the X water injection wells from the M oil production wells, to obtain Y oil production wells, wherein X is an integer greater than 0 and less than N, and Y is an integer greater than X and less than M.

[0028] Optionally, by determining X water injection wells from N water injection wells and determining Y oil production wells from M oil production wells, various parameters required for calculating the effective utilization rate of water injection can be obtained, so as to more accurately calculate the effective utilization rate of water injection.

[0029] In an optional embodiment, X water injection wells are determined from N water injection wells, and oil production wells corresponding to the X water injection wells are determined from M oil production wells to obtain Y oil production wells, including: classifying the N water injection wells according to displacement characteristics to obtain classification results, wherein the displacement characteristics are used to indicate the mode characteristics of using injected water to displace crude oil in the oil layer; based on the classification results, determining a first water injection well whose displacement characteristics are homogeneous characteristics from the N water injection wells, wherein the homogeneous characteristics are used to indicate the characteristics of uniform distribution of the formation in the first water injection well; based on the first water injection well, obtaining X water injection wells; based on the X water injection wells, determining Y oil production wells from the M oil production wells.

[0030] Optionally, the displacement characteristics include homogeneous characteristics, fracture conductivity characteristics, composite conductivity characteristics and overlap characteristics, among which, homogeneous characteristics: refers to the formation around the water injection well has uniform permeability and porosity, and the injected water can diffuse evenly to the surrounding formations; fracture conductivity characteristics: refers to the formation around the water injection well has fractures or fracture networks, and the injected water mainly flows through these fractures, resulting in a faster diffusion rate of water. Composite conductivity characteristics: refers to the formation around the water injection well has both homogeneous and fracture conductivity characteristics, and the injected water diffuses through the homogeneous formation and flows through the fractures. Overlap characteristics: refers to the formation around the water injection well has multiple layers of different properties, each layer has different displacement characteristics, and the injected water flows in different ways in different formations. The pressure test data of the water injection well can be used to obtain X water injection wells with homogeneous characteristics and the corresponding Y oil production wells. The purpose of obtaining a water injection well with homogeneous characteristics is to ensure that the injected water can be evenly distributed in the reservoir and effectively promote the displacement of oil, so as to ensure that the water injection process can achieve the best effect, so as to improve the accuracy of the effective utilization rate of water injection in the target reservoir.

[0031] Step S106, obtaining the cumulative water injection volumes corresponding to the N water injection wells and the cumulative water production volumes corresponding to the Y oil production wells.

[0032] Optionally, the cumulative water injection volume of the water injection well and the cumulative water production volume of the oil production well at the sampling time can be obtained through the historical production data of the oil and water wells. The cumulative water injection volume of the water injection well refers to the cumulative amount of water injected into the underground oil layer by the water injection well from the date of commissioning to the sampling time. The cumulative water production volume of the oil production well refers to the cumulative amount of water extracted from the underground oil layer by the oil production well from the date of commissioning to the sampling time. The cumulative water injection volume of the water injection well and the cumulative water production volume of the oil production well are important indicators for measuring the effect of oil and gas production. By comparing the cumulative water injection volume and the cumulative water production volume, the water injection effect and the oil production effect can be evaluated, and the production potential and production efficiency of the oil reservoir can be judged.

[0033] Step S108, determining the effective utilization rate of water injection of the target oil reservoir based on the cumulative water injection volumes corresponding to the N water injection wells and the cumulative water production volumes corresponding to the Y oil production wells.

[0034] Optionally, the effective utilization rate of injection water of the target reservoir is calculated under the assumption that the reservoir is homogeneous. A homogeneous reservoir means that the rock and fluid properties in the reservoir are evenly distributed in space without obvious differences. Assuming that the reservoir is homogeneous can simplify calculations and reduce the complexity of analysis, the reservoir is considered as a whole for calculation, and there is no need to consider the possible heterogeneity in the reservoir.

[0035] In an optional embodiment, based on the cumulative water injection volumes corresponding to the N water injection wells and the cumulative water production volumes corresponding to the Y oil production wells, the effective utilization rate of water injection of the target oil reservoir is determined, including: determining a first water injection volume based on the cumulative water injection volumes corresponding to the X water injection wells and the cumulative water production volumes corresponding to the Y oil production wells, wherein the first water injection volume is used to indicate the water injection volume required for the pressure to be restored to the current pressure level under homogeneous conditions; determining the effective utilization rate of water injection based on the first water injection volume and the cumulative water injection volumes corresponding to the N water injection wells.

[0036] Optionally, based on the cumulative water injection volumes corresponding to X water injection wells and the cumulative water production volumes corresponding to Y oil production wells, the water injection volumes required to restore the pressure to the current pressure level under homogeneous conditions can be determined. Based on the first water injection volume and the cumulative water injection volumes corresponding to N water injection wells, the effective utilization rate of water injection can be accurately determined.

[0037] In an optional embodiment, determining the effective utilization rate of water injection based on the first water injection volume and the cumulative water injection volumes corresponding to the N water injection wells respectively includes: determining the effective utilization rate of water injection based on the first water injection volume and the cumulative water injection volumes corresponding to the N water injection wells respectively by the following method:

[0038]

[0039] Wherein, η is the effective utilization rate of water injection, Q1 is the first water injection volume, Q i It is the cumulative water injection volume corresponding to the i-th water injection well among the N water injection wells.

[0040] Optionally, the effective utilization rate of water injection at the sampling time of the target reservoir can be calculated by using the ratio of the first water injection volume required to restore the pressure to the current pressure level under homogeneous conditions to the actual cumulative water injection volume at the sampling time of the target reservoir. Through the above method, the parameter calculation is simple and easy to obtain, and the calculated effective utilization rate of water injection is more realistic and accurate.

[0041] In an optional embodiment, determining a first water injection amount based on the cumulative water injection amounts corresponding to the X water injection wells and the cumulative water production amounts corresponding to the Y oil production wells includes: obtaining formation pressures corresponding to the X water injection wells and the formation pressures corresponding to the Y oil production wells; determining a first formation pressure based on the formation pressures corresponding to the X water injection wells and the formation pressures corresponding to the Y oil production wells, wherein the first formation pressure is used to indicate a comprehensive formation pressure level of the X water injection wells and the Y oil production wells; obtaining an original formation pressure of the target oil reservoir; determining a second water injection amount based on the cumulative water injection amounts corresponding to the X water injection wells, the cumulative water production amounts corresponding to the Y oil production wells, the first formation pressure, and the original formation pressure, wherein the second water injection amount is used to indicate a water injection amount required to increase the formation pressure by 1 MPa under homogeneous conditions; and determining the first water injection amount based on the second water injection amount.

[0042] Optionally, the formation pressures corresponding to X water injection wells and Y oil production wells can be obtained through the target reservoir test data. The formation pressures corresponding to the X water injection wells and the formation pressures corresponding to the Y oil production wells are added together, and the result is divided by X plus Y. The average value obtained is the first formation pressure. The original formation pressure of the target reservoir can be obtained through the well test data of all oil and water wells in the target reservoir. Based on the cumulative water injection volume corresponding to the X water injection wells, the cumulative water production volume corresponding to the Y oil production wells, the first formation pressure, and the original formation pressure, the second water injection volume required to increase the formation pressure by 1 MPa under homogeneous conditions is determined, and then based on the second water injection volume, the water injection volume required to restore the pressure to the current pressure level under homogeneous conditions is determined.

[0043] In an optional embodiment, determining the second water injection amount based on the cumulative water injection amounts corresponding to the X water injection wells, the cumulative water production amounts corresponding to the Y oil production wells, the first formation pressure, and the original formation pressure includes: determining the second water injection amount based on the cumulative water injection amounts corresponding to the X water injection wells, the cumulative water production amounts corresponding to the Y oil production wells, the first formation pressure, and the original formation pressure in the following manner:

[0044]

[0045] Wherein, IPV is the second water injection volume, Q j Q is the cumulative water injection volume corresponding to the jth water injection well among the X water injection wells. k is the cumulative water production corresponding to the kth oil production well among the Y oil production wells, P1 is the first formation pressure, and P2 is the original formation pressure.

[0046] Optionally, the second water injection volume can be accurately determined based on the sum of the cumulative water injection volumes corresponding to the X water injection wells, the sum of the cumulative water production volumes corresponding to the Y oil production wells, and the difference between the first formation pressure and the original formation pressure.

[0047] In an optional embodiment, the first water injection volume is determined based on the second water injection volume, including: obtaining the formation pressures corresponding to N water injection wells and the formation pressures corresponding to M oil production wells; determining the second formation pressure based on the formation pressures corresponding to the N water injection wells and the formation pressures corresponding to the M oil production wells, wherein the second formation pressure is used to indicate the comprehensive formation pressure level of the N water injection wells and the M oil production wells; determining the first water injection volume based on the second water injection volume, the second formation pressure, and the original formation pressure.

[0048] Optionally, the formation pressures corresponding to N water injection wells and M oil production wells can be obtained through the well test data of all oil and water wells in the target reservoir. The formation pressures corresponding to the N water injection wells and the formation pressures corresponding to the M oil production wells are added together and divided by N plus M. The average value obtained is the second formation pressure. Based on the second water injection volume, the second formation pressure, and the original formation pressure, the water injection volume required to restore the pressure to the current pressure level under homogeneous conditions is determined.

[0049] In an optional embodiment, determining the first water injection amount based on the second water injection amount, the second formation pressure, and the original formation pressure includes: determining the first water injection amount based on the second water injection amount, the second formation pressure, and the original formation pressure in the following manner:

[0050] Q1=IPV*N*(P3-P2)

[0051] Among them, Q1 is the first water injection volume, IPV is the second water injection volume, P3 is the second formation pressure, and P2 is the original formation pressure.

[0052] Optionally, the first water injection volume can be accurately determined based on the second water injection volume, the number N of water injection wells, and the difference between the second formation pressure and the original formation pressure.

[0053] Through the above steps S102 to S108, the purpose of accurately determining the effective utilization rate of water injection in the target reservoir is achieved based on the ratio of the water injection volume required for the pressure to be restored to the current level under homogeneous conditions and the actual cumulative water injection volume, thereby achieving the technical effect of improving the accuracy of the effective utilization rate of water injection, and further solving the technical problem of low accuracy in the evaluation of water injection utilization status caused by incomplete consideration of factors in the relevant technology of oil reservoir water injection treatment methods.

[0054] Based on the above embodiment and optional embodiment, the present invention proposes an optional implementation mode, the method includes:

[0055] Step S1, obtaining N water injection wells included in the target oil reservoir, and M oil production wells corresponding to the N water injection wells, wherein N is an integer greater than 0, and M is an integer greater than N.

[0056] Step S2, classifying the N water injection wells according to the displacement characteristics to obtain classification results.

[0057] Step S3: Based on the classification result, determine the first water injection well whose displacement characteristic is a homogeneous characteristic from the N water injection wells.

[0058] Step S4, based on the first water injection well, obtain X water injection wells.

[0059] Step S5, based on the X water injection wells, determine Y oil production wells from the M oil production wells.

[0060] Step S6, obtaining the cumulative water injection volume corresponding to the N water injection wells and the cumulative water production volume corresponding to the Y oil production wells.

[0061] Step S7, obtaining the formation pressures corresponding to the X water injection wells and the formation pressures corresponding to the Y oil production wells.

[0062] Step S8, calculating the average of the formation pressures corresponding to the X water injection wells and the formation pressures corresponding to the Y oil production wells as the first formation pressure, wherein the first formation pressure is used to indicate the comprehensive formation pressure level of the X water injection wells and the Y oil production wells.

[0063] Step S9, obtaining the original formation pressure of the target oil reservoir.

[0064] Step S10, based on the cumulative water injection volumes corresponding to the X water injection wells, the cumulative water production volumes corresponding to the Y oil production wells, the first formation pressure, and the original formation pressure, determine the second water injection volume in the following manner, wherein the second water injection volume is used to indicate the water injection volume required to increase the formation pressure by 1 MPa under homogeneous conditions:

[0065]

[0066] Among them, IPV is the second water injection volume, Q j Q is the cumulative water injection volume corresponding to the jth water injection well among X water injection wells. k is the cumulative water production corresponding to the kth oil production well among Y oil production wells, P1 is the first formation pressure, and P2 is the original formation pressure.

[0067] Step S11, obtaining the formation pressures corresponding to the N water injection wells and the formation pressures corresponding to the M oil production wells.

[0068] Step S12, calculate the average value of the formation pressures corresponding to the N water injection wells and the formation pressures corresponding to the M oil production wells as the second formation pressure, wherein the second formation pressure is used to indicate the comprehensive formation pressure level of the N water injection wells and the M oil production wells.

[0069] Step S13, based on the second water injection volume, the second formation pressure, and the original formation pressure, the first water injection volume is determined in the following manner:

[0070] Q1=IPV*N*(P3-P2)

[0071] Among them, Q1 is the first water injection volume, IPV is the second water injection volume, P3 is the second formation pressure, and P2 is the original formation pressure.

[0072] Step S14, based on the first water injection volume and the cumulative water injection volumes corresponding to the N water injection wells, the effective utilization rate of water injection is determined in the following manner:

[0073]

[0074] Among them, η is the effective utilization rate of water injection, Q1 is the first water injection volume, Q i is the cumulative water injection volume corresponding to the i-th injection well among N injection wells.

[0075] The embodiments of the present invention can at least achieve the following technical effects: 1) The pressure conversion method is used to realize the transformation from water injection utilization rate to water injection effective utilization rate, and the calculation result is more scientific and reasonable; 2) The scientificity and rationality of water injection utilization status evaluation are improved, and the research on water drive law of oil reservoirs, water injection optimization adjustment, and residual oil potential are effectively guided; 3) The effectiveness of water injection is fully considered, and the calculation result is more in line with reality, and the parameter calculation is simple, easy to obtain, and highly operable, which effectively guides fine water injection adjustment and residual oil potential; 4) The pertinence and practicality of water injection adjustment and encryption adjustment can be greatly improved.

[0076] Based on the above embodiments and optional embodiments, the present invention proposes an example of determining the water flooding front position based on the effective utilization rate of water injection:

[0077] The S6 area 6 oil reservoir is located in the middle of the northern Shaanxi slope. It has a gentle structure and is a wide and gentle west-dipping fault. It belongs to the delta front subfacies. It has favorable microfacies types such as underwater distributary channels, estuary bars, underwater natural levees, and distant sand bars. The average oil layer thickness is 18.4 meters, the average porosity is 13.7%, and the average permeability is 2.29mD. It is an ultra-low permeability oil reservoir.

[0078] The water drive front refers to the phenomenon that during the water drive process, water is injected to push the front of the oil (i.e., the front edge) to move deeper into the reservoir. In oil field exploitation, the oil is generally first partially discharged from the reservoir by natural pressure or injection of other propellants, and then water is injected to push the front of the oil to further drive out the oil in the reservoir. Figure 2 As shown, Figure 2 is a schematic diagram of an optional water drive front according to an embodiment of the present invention. The water drive front calculation formula can be used, and considering the effectiveness of water injection, the waterline advancement position in different directions of the well group can be calculated by the following formula:

[0079]

[0080] Among them, f w '(s w ) is the slope of the water content and water content increase rate curve, where the water content and water content increase rate curve is a curve that describes the change of reservoir water content over time during oil production, such as Figure 3 As shown, Figure 3 is a schematic diagram of an optional water content and water content rise rate curve according to an embodiment of the present invention, which is derived from the phase permeability curve. w '(s w ) has a value of 4.826.

[0081] Φ is the average porosity of each oil well and water well in the well group. For example, Table 1 below shows the porosity of oil and water wells corresponding to the W16-15 well group in the S6 reservoir:

[0082] Table 1

[0083]

[0084] A is the area controlled by each oil well and water well in the well group. For example, the area controlled by each oil well and water well in the W16-15 well group of the S6 reservoir is as follows: Figure 4 As shown, Figure 4 It is a schematic diagram of an optional water injection unit area according to an embodiment of the present invention, and the area controlled by each oil well and water is recorded as A1, A2, A3, A4, A5, A6, A7, and A8 respectively. The following Table 2 is a calculation table of the plane water injection unit area of ​​the W16-15 well group in the S6 oil reservoir:

[0085] Table 2

[0086]

[0087] The cumulative water injection volume of the oil wells in any direction at a certain point in time is obtained by using the pressure conversion method, as shown in Table 3 below. The table shows the cumulative water injection volume of the oil wells in any direction of the W16-15 well group in the S6 reservoir at a certain point in time:

[0088] Table 3

[0089]

[0090] The formula can be used to obtain the water drive front position at different time points in the direction of each oil well in the W16-15 well group as shown in Table 4:

[0091] Table 4

[0092]

[0093] According to the calculation results, the water drive positions of the W16-15 well group at different times and in different directions can be obtained, such as Figure 5 As shown, Figure 5 is a schematic diagram of another optional water drive front according to an embodiment of the present invention.

[0094] In order to detect the longitudinal water washing degree and water flooding characteristics in different directions and different injection-production well spacings in the same area, study the formation mechanism and occurrence state of microscopic residual oil, evaluate the longitudinal water drive status, and indicate the direction for residual oil analysis, three inspection wells were arranged in different directions and different well spacings in the W16-15 well group, such as Figure 6 As shown, Figure 6 It is a schematic diagram of an optional inspection well deployment according to an embodiment of the present invention. The area first adopted a square inverted nine-point well network with a well spacing of 250-300 meters, which was later encrypted to form the current irregular well network.

[0095] like Figure 6 As shown, the WJ16-151 inspection well is deployed between the W16-15 well group and the W15-18 well group, located in the northeast of the W16-15 well group, basically consistent with the main stress direction (NE67°), and about 200m away from the injection well W16-15.

[0096] Still Figure 6 As shown, the WJ16-152 inspection well is deployed between the W16-15 well group and the W15-17 well group, located in the northeast of the W16-15 well group, approximately NE30°, with an angle of about 35° with the principal stress direction (NE67°), and is about 130m away from the injection well W16-15.

[0097] Still Figure 6 As shown, the WJ16-153 inspection well is deployed between the W16-15 well group and the W15-16 well group, located in the northwest of the W16-15 well group, approximately around NW35°, nearly perpendicular to the principal stress direction (NE67°), and about 110m away from the injection well W16-15.

[0098] According to the previous calculation, the water drive front position of the W16-15 well group can be seen in the map. In 2020, the water drive front position has reached the two inspection wells WJ16-151 and WJ16-152, but has not reached the WJ16-153 inspection well. From the test production results of the three inspection wells, the water content of the two inspection wells WJ16-151 and WJ16-152 is relatively high, and the water content of the WJ16-153 inspection well is only about 20%. Figures 7a to 7c is a schematic diagram of an optional well test production curve according to an embodiment of the present invention, such as Figures 7a to 7c As shown in the figure, the calculation results of the water drive front are consistent with the test production results, which can prove that the position of the water drive front can be determined based on the effective utilization rate of water injection, and can provide a reliable technical basis for the next step of reservoir infill adjustment, tapping the potential of remaining oil, and improving the ultimate recovery rate.

[0099] In this embodiment, a reservoir water injection treatment device is also provided, which is used to implement the above-mentioned embodiments and preferred implementation modes, and the descriptions that have been made will not be repeated. As used below, the terms "module" and "device" can implement a combination of software and / or hardware for a predetermined function. Although the devices described in the following embodiments are preferably implemented in software, the implementation of hardware, or a combination of software and hardware, is also possible and conceivable.

[0100] According to an embodiment of the present invention, there is also provided an embodiment of a device for implementing the above-mentioned oil reservoir water injection treatment method. Figure 8 is a schematic diagram of the structure of an oil reservoir water injection treatment device according to an embodiment of the present invention. Figure 8 As shown, the above-mentioned reservoir water injection processing device includes: a first acquisition module 802, a first determination module 804, a second acquisition module 806, and a second determination module 808, wherein:

[0101] A first acquisition module 802 is used to acquire N water injection wells included in the target oil reservoir, and M oil production wells corresponding to the N water injection wells, wherein N is an integer greater than 0, and M is an integer greater than N;

[0102] The first determination module 804 is connected to the first acquisition module 802, and is used to determine X water injection wells from the N water injection wells, and determine the oil production wells corresponding to the X water injection wells from the M oil production wells, to obtain Y oil production wells, where X is an integer greater than 0 and less than N, and Y is an integer greater than X and less than M;

[0103] The second acquisition module 806 is connected to the first determination module 804 and is used to obtain the cumulative water injection volume corresponding to the N water injection wells and the cumulative water production volume corresponding to the Y oil production wells;

[0104] The second determination module 808 is connected to the second acquisition module 806, and is used to determine the effective utilization rate of water injection of the target oil reservoir based on the cumulative water injection volume corresponding to the N water injection wells and the cumulative water production volume corresponding to the Y oil production wells.

[0105] A first acquisition module 802 is provided to acquire N water injection wells included in the target oil reservoir, and M oil production wells corresponding to the N water injection wells, wherein N is an integer greater than 0, and M is an integer greater than N; a first determination module 804 is provided to determine X water injection wells from the N water injection wells, and to determine the oil production wells corresponding to the X water injection wells from the M oil production wells, to obtain Y oil production wells, wherein X is an integer greater than 0 and less than N, and Y is an integer greater than X and less than M; a second acquisition module 806 is provided to acquire the cumulative water injection volume corresponding to the N water injection wells, and the cumulative water production volume corresponding to the Y oil production wells; a second determination module 808 is provided to determine the effective utilization rate of water injection of the target oil reservoir based on the cumulative water injection volume corresponding to the N water injection wells, and the cumulative water production volume corresponding to the Y oil production wells. The purpose of accurately determining the effective utilization rate of water injection in the target reservoir is achieved based on the ratio of the water injection volume required to restore the pressure to the current level under homogeneous conditions and the actual cumulative water injection volume, thereby achieving the technical effect of improving the accuracy of the effective utilization rate of water injection, and further solving the technical problem of low accuracy in the evaluation of water injection utilization status caused by incomplete consideration of factors in the relevant technologies of reservoir water injection treatment methods.

[0106] In an optional embodiment, the above-mentioned first determination module includes: a first classification submodule, which is used to classify N water injection wells according to displacement characteristics to obtain classification results, wherein the displacement characteristics are used to indicate the pattern characteristics of using injected water to displace crude oil in the oil layer; a first determination submodule, which is used to determine, based on the classification results, a first water injection well whose displacement characteristics are homogeneous characteristics from the N water injection wells, wherein the homogeneous characteristics are used to indicate that the formation in the first water injection well presents a uniformly distributed characteristic; a second determination submodule, which is used to obtain X water injection wells based on the first water injection well; and a third determination submodule, which is used to determine Y oil production wells from M oil production wells based on the X water injection wells.

[0107] In an optional embodiment, the above-mentioned second determination module includes: a fourth determination submodule, used to determine the first water injection volume based on the cumulative water injection volumes corresponding to the X water injection wells and the cumulative water production volumes corresponding to the Y oil production wells, wherein the first water injection volume is used to indicate the water injection volume required for the pressure to be restored to the current pressure level under homogeneous conditions; a fifth determination submodule, used to determine the effective utilization rate of water injection based on the first water injection volume and the cumulative water injection volumes corresponding to the N water injection wells.

[0108] In an optional embodiment, the fifth determination submodule includes: a sixth determination submodule, configured to determine the effective utilization rate of water injection based on the first water injection volume and the cumulative water injection volumes corresponding to the N water injection wells in the following manner: Among them, η is the effective utilization rate of water injection, Q1 is the first water injection volume, Q i is the cumulative water injection volume corresponding to the i-th injection well among N injection wells.

[0109] In an optional embodiment, the fourth determination submodule includes: a first acquisition submodule, used to acquire the formation pressures corresponding to the X water injection wells and the formation pressures corresponding to the Y oil production wells; a seventh determination submodule, used to determine the first formation pressure based on the formation pressures corresponding to the X water injection wells and the formation pressures corresponding to the Y oil production wells, wherein the first formation pressure is used to indicate the comprehensive formation pressure level of the X water injection wells and the Y oil production wells; a second acquisition submodule, used to acquire the original formation pressure of the target oil reservoir; an eighth determination submodule, used to determine the second water injection amount based on the cumulative water injection amount corresponding to the X water injection wells, the cumulative water production amount corresponding to the Y oil production wells, the first formation pressure, and the original formation pressure, wherein the second water injection amount is used to indicate the water injection amount required to increase the formation pressure by 1 MPa under homogeneous conditions; and a ninth determination submodule, used to determine the first water injection amount based on the second water injection amount.

[0110] In an optional embodiment, the eighth determination submodule includes: a tenth determination submodule, configured to determine the second water injection volume based on the cumulative water injection volumes corresponding to the X water injection wells, the cumulative water production volumes corresponding to the Y oil production wells, the first formation pressure, and the original formation pressure in the following manner: Among them, IPV is the second water injection volume, Q j Q is the cumulative water injection volume corresponding to the jth water injection well among X water injection wells. k is the cumulative water production corresponding to the kth oil production well among Y oil production wells, P1 is the first formation pressure, and P2 is the original formation pressure.

[0111] In an optional embodiment, the ninth determination submodule includes: a third acquisition submodule, used to acquire the formation pressures corresponding to the N water injection wells and the formation pressures corresponding to the M oil production wells; an eleventh determination submodule, used to determine the second formation pressure based on the formation pressures corresponding to the N water injection wells and the formation pressures corresponding to the M oil production wells, wherein the second formation pressure is used to indicate the comprehensive formation pressure level of the N water injection wells and the M oil production wells; a twelfth determination submodule, used to determine the first water injection volume based on the second water injection volume, the second formation pressure, and the original formation pressure.

[0112] In an optional embodiment, the above-mentioned twelfth determination submodule includes: a thirteenth determination submodule, used to determine the first water injection volume based on the second water injection volume, the second formation pressure, and the original formation pressure in the following manner: Q1=IPV*N*(P3-P2), wherein Q1 is the first water injection volume, IPV is the second water injection volume, P3 is the second formation pressure, and P2 is the original formation pressure.

[0113] It should be noted that the above modules can be implemented by software or hardware. For example, for the latter, it can be implemented in the following ways: the above modules can be located in the same processor; or the above modules can be located in different processors in any combination.

[0114] It should be noted that the first acquisition module 802, the first determination module 804, the second acquisition module 806, and the second determination module 808 correspond to steps S102 to S108 in the embodiment, and the examples and application scenarios implemented by the modules and the corresponding steps are the same, but are not limited to the contents disclosed in the above embodiments. It should be noted that the modules as part of the device can be run in a computer terminal.

[0115] It should be noted that the optional or preferred implementation of this embodiment can refer to the relevant description in the embodiment, which will not be repeated here.

[0116] The above-mentioned reservoir water injection processing device may also include a processor and a memory. The above-mentioned first acquisition module 802, first determination module 804, second acquisition module 806, second determination module 808, etc. are all stored in the memory as program modules, and the processor executes the above-mentioned program modules stored in the memory to realize corresponding functions.

[0117] The processor includes a kernel, which retrieves the corresponding program module from the memory. The kernel may be one or more. The memory may include non-permanent memory in a computer-readable medium, random access memory (RAX) and / or non-volatile memory, such as read-only memory (ROX) or flash memory (flash RAX). The memory includes at least one memory chip.

[0118] According to an embodiment of the present application, an embodiment of a non-volatile storage medium is also provided. Optionally, in this embodiment, the non-volatile storage medium includes a stored program, wherein when the program is executed, the device where the non-volatile storage medium is located is controlled to execute any one of the above-mentioned reservoir water injection treatment methods.

[0119] Optionally, in this embodiment, the non-volatile storage medium may be located in any computer terminal in a computer terminal group in a computer network, or in any mobile terminal in a mobile terminal group, and the non-volatile storage medium includes a stored program.

[0120] Optionally, when the program is running, the device where the non-volatile storage medium is located is controlled to perform the following functions: obtain N water injection wells included in the target oil reservoir, and M oil production wells corresponding to the N water injection wells, wherein N is an integer greater than 0, and M is an integer greater than N; determine X water injection wells from the N water injection wells, and determine the oil production wells corresponding to the X water injection wells from the M oil production wells, to obtain Y oil production wells, wherein X is an integer greater than 0 and less than N, and Y is an integer greater than X and less than M; obtain the cumulative water injection volume corresponding to the N water injection wells, and the cumulative water production volume corresponding to the Y oil production wells; based on the cumulative water injection volume corresponding to the N water injection wells, and the cumulative water production volume corresponding to the Y oil production wells, determine the effective utilization rate of water injection of the target oil reservoir.

[0121] According to an embodiment of the present application, an embodiment of a processor is also provided. Optionally, in this embodiment, the processor is used to run a program, wherein when the program is run, any one of the above-mentioned reservoir water injection treatment methods is executed.

[0122] According to an embodiment of the present application, there is also provided an embodiment of a computer program product, which, when executed on a data processing device, is suitable for executing a program that initializes any one of the steps of the above-mentioned reservoir water injection treatment method.

[0123] Optionally, the above-mentioned computer program product, when executed on a data processing device, is suitable for executing a program that is initialized with the following method steps: obtaining N water injection wells included in the target oil reservoir, and M oil production wells corresponding to the N water injection wells, wherein N is an integer greater than 0, and M is an integer greater than N; determining X water injection wells from the N water injection wells, and determining the oil production wells corresponding to the X water injection wells from the M oil production wells, to obtain Y oil production wells, wherein X is an integer greater than 0 and less than N, and Y is an integer greater than X and less than M; obtaining the cumulative water injection volume corresponding to the N water injection wells, and the cumulative water production volume corresponding to the Y oil production wells; based on the cumulative water injection volume corresponding to the N water injection wells, and the cumulative water production volume corresponding to the Y oil production wells, determining the effective utilization rate of water injection of the target oil reservoir.

[0124] Optionally, the computer program product is further suitable for executing a program initialized with the following method steps: classifying N water injection wells according to displacement characteristics to obtain classification results, wherein the displacement characteristics are used to indicate the pattern characteristics of using injected water to displace crude oil in the oil layer; based on the classification results, determining a first water injection well whose displacement characteristics are homogeneous characteristics from the N water injection wells, wherein the homogeneous characteristics are used to indicate that the formation in the first water injection well presents a uniformly distributed characteristic; based on the first water injection well, obtaining X water injection wells; based on the X water injection wells, determining Y oil production wells from M oil production wells.

[0125] Optionally, the computer program product is further suitable for executing a program initialized with the following method steps: determining a first water injection volume based on the cumulative water injection volumes corresponding to the X water injection wells and the cumulative water production volumes corresponding to the Y oil production wells, wherein the first water injection volume is used to indicate the water injection volume required for the pressure to be restored to the current pressure level under homogeneous conditions; determining the effective utilization rate of water injection based on the first water injection volume and the cumulative water injection volumes corresponding to the N water injection wells.

[0126] Optionally, the computer program product is further adapted to execute a program that is initialized with the following method steps: based on the first water injection volume and the cumulative water injection volumes corresponding to the N water injection wells, determining the effective utilization rate of water injection in the following manner: Among them, η is the effective utilization rate of water injection, Q1 is the first water injection volume, Q i is the cumulative water injection volume corresponding to the i-th injection well among N injection wells.

[0127] Optionally, the computer program product is further adapted to execute a program that is initialized with the following method steps: obtaining formation pressures corresponding to the X water injection wells and the Y oil production wells; determining a first formation pressure based on the formation pressures corresponding to the X water injection wells and the Y oil production wells, wherein the first formation pressure is used to indicate a comprehensive formation pressure level of the X water injection wells and the Y oil production wells; obtaining an original formation pressure of the target oil reservoir; determining a second water injection amount based on the cumulative water injection amounts corresponding to the X water injection wells, the cumulative water production amounts corresponding to the Y oil production wells, the first formation pressure, and the original formation pressure, wherein the second water injection amount is used to indicate the water injection amount required to increase the formation pressure by 1 MPa under homogeneous conditions; and determining the first water injection amount based on the second water injection amount.

[0128] Optionally, the computer program product is further adapted to execute a program that is initialized with the following method steps: based on the cumulative water injection volumes corresponding to the X water injection wells, the cumulative water production volumes corresponding to the Y oil production wells, the first formation pressure, and the original formation pressure, determining the second water injection volume in the following manner: Among them, IPV is the second water injection volume, Q jQ is the cumulative water injection volume corresponding to the jth water injection well among X water injection wells. k is the cumulative water production corresponding to the kth oil production well among Y oil production wells, P1 is the first formation pressure, and P2 is the original formation pressure.

[0129] Optionally, the above-mentioned computer program product is also suitable for executing an initialized program having the following method steps: obtaining the formation pressures corresponding to N water injection wells and the formation pressures corresponding to M oil production wells; determining a second formation pressure based on the formation pressures corresponding to the N water injection wells and the formation pressures corresponding to the M oil production wells, wherein the second formation pressure is used to indicate the comprehensive formation pressure level of the N water injection wells and the M oil production wells; determining the first water injection volume based on the second water injection volume, the second formation pressure, and the original formation pressure.

[0130] Optionally, the above-mentioned computer program product is also suitable for executing an initialization program having the following method steps: based on the second water injection volume, the second formation pressure, and the original formation pressure, the first water injection volume is determined in the following manner: Q1=IPV*N*(P3-P2), wherein Q1 is the first water injection volume, IPV is the second water injection volume, P3 is the second formation pressure, and P2 is the original formation pressure.

[0131] like Fig. 9 As shown, an embodiment of the present invention provides an electronic device, which includes a processor, a memory, and a program stored in the memory and executable on the processor. When the processor executes the program, the following steps are implemented: obtaining N water injection wells included in the target oil reservoir, and M oil production wells corresponding to the N water injection wells, wherein N is an integer greater than 0, and M is an integer greater than N; determining X water injection wells from the N water injection wells, and determining the oil production wells corresponding to the X water injection wells from the M oil production wells, to obtain Y oil production wells, wherein X is an integer greater than 0 and less than N, and Y is an integer greater than X and less than M; obtaining the cumulative water injection volume corresponding to the N water injection wells, and the cumulative water production volume corresponding to the Y oil production wells; determining the effective utilization rate of water injection of the target oil reservoir based on the cumulative water injection volume corresponding to the N water injection wells, and the cumulative water production volume corresponding to the Y oil production wells.

[0132] In the above embodiments of the present invention, the description of each embodiment has its own emphasis. For parts that are not described in detail in a certain embodiment, reference can be made to the relevant descriptions of other embodiments.

[0133] In the several embodiments provided in this application, it should be understood that the disclosed technical content can be implemented in other ways. Among them, the device embodiments described above are only schematic. For example, the division of the above modules can be a logical function division. There may be other division methods in actual implementation, such as multiple modules or components can be combined or integrated into another system, or some features can be ignored or not executed. Another point is that the mutual coupling or direct coupling or communication connection shown or discussed can be through some interfaces, modules or indirect coupling or communication connection of modules, which can be electrical or other forms.

[0134] The modules described above as separate components may or may not be physically separated, and the components shown as modules may or may not be physical modules, that is, they may be located in one place or distributed on multiple modules. Some or all of the modules may be selected according to actual needs to achieve the purpose of the present embodiment.

[0135] In addition, each functional module in each embodiment of the present invention may be integrated into one processing module, or each module may exist physically separately, or two or more modules may be integrated into one module. The above-mentioned integrated module may be implemented in the form of hardware or in the form of software functional modules.

[0136] If the above-mentioned integrated module is implemented in the form of a software function module and sold or used as an independent product, it can be stored in a computer-readable non-volatile storage medium. Based on this understanding, the technical solution of the present invention is essentially or the part that contributes to the prior art or all or part of the technical solution can be embodied in the form of a software product. The computer software product is stored in a non-volatile storage medium, including a number of instructions to enable a computer device (which can be a personal computer, server or network device, etc.) to perform all or part of the steps of the various embodiments of the present invention. The aforementioned non-volatile storage medium includes: U disk, read-only memory (ROM, Read-Only Memory), random access memory (RAM, Random Access Memory), mobile hard disk, magnetic disk or optical disk and other media that can store program codes.

[0137] The above are only preferred embodiments of the present invention. It should be pointed out that, for ordinary technicians in this technical field, several improvements and modifications can be made without departing from the principles of the present invention. These improvements and modifications should also be regarded as the scope of protection of the present invention.

Claims

1. A method for treating oil reservoir water injection, characterized in that: include: Obtain N water injection wells included in the target oil reservoir, and M oil production wells corresponding to the N water injection wells, where N is an integer greater than 0, and M is an integer greater than N; Determine X water injection wells from the N water injection wells, and determine the oil production wells corresponding to the X water injection wells from the M oil production wells, to obtain Y oil production wells, wherein X is an integer greater than 0 and less than N, and Y is an integer greater than X and less than M; Obtaining the cumulative water injection volumes corresponding to the N water injection wells and the cumulative water production volumes corresponding to the Y oil production wells; Based on the cumulative water injection volumes corresponding to the N water injection wells and the cumulative water production volumes corresponding to the Y oil production wells, the effective utilization rate of water injection of the target oil reservoir is determined.

2. The method according to claim 1, characterized in that: The step of determining X water injection wells from the N water injection wells, and determining oil production wells corresponding to the X water injection wells from the M oil production wells, to obtain Y oil production wells, comprises: Classifying the N water injection wells according to displacement characteristics to obtain classification results, wherein the displacement characteristics are used to indicate the mode characteristics of using injected water to displace crude oil in the oil layer; Based on the classification result, determining a first water injection well whose displacement characteristic is a homogeneous characteristic from the N water injection wells, wherein the homogeneous characteristic is used to indicate that the formation in the first water injection well presents a characteristic of uniform distribution; Based on the first water injection well, obtaining the X water injection wells; Based on the X water injection wells, the Y oil production wells are determined from the M oil production wells.

3. The method according to claim 1, characterized in that: The determining the effective utilization rate of water injection of the target oil reservoir based on the cumulative water injection volumes respectively corresponding to the N water injection wells and the cumulative water production volumes respectively corresponding to the Y oil production wells comprises: Based on the accumulated water injection volumes corresponding to the X water injection wells and the accumulated water production volumes corresponding to the Y oil production wells, a first water injection volume is determined, wherein the first water injection volume is used to indicate the water injection volume required to restore the pressure to the current pressure level under homogeneous conditions; The effective utilization rate of water injection is determined based on the first water injection volume and the cumulative water injection volumes corresponding to the N water injection wells.

4. The method according to claim 3, characterized in that The determining of the effective utilization rate of water injection based on the first water injection volume and the cumulative water injection volumes respectively corresponding to the N water injection wells includes: Based on the first water injection volume and the cumulative water injection volumes corresponding to the N water injection wells, the effective utilization rate of water injection is determined in the following manner: Wherein, η is the effective utilization rate of water injection, Q1 is the first water injection volume, Q i It is the cumulative water injection volume corresponding to the i-th water injection well among the N water injection wells.

5. The method according to claim 3, characterized in that: The determining of the first water injection volume based on the accumulated water injection volumes respectively corresponding to the X water injection wells and the accumulated water production volumes respectively corresponding to the Y oil production wells comprises: Obtaining formation pressures corresponding to the X water injection wells and the Y oil production wells; Determine a first formation pressure based on the formation pressures corresponding to the X water injection wells and the formation pressures corresponding to the Y oil production wells, wherein the first formation pressure is used to indicate a comprehensive formation pressure level of the X water injection wells and the Y oil production wells; Obtaining the original formation pressure of the target oil reservoir; Determine a second water injection volume based on the cumulative water injection volumes corresponding to the X water injection wells, the cumulative water production volumes corresponding to the Y oil production wells, the first formation pressure, and the original formation pressure, wherein the second water injection volume is used to indicate the water injection volume required to increase the formation pressure by 1 MPa under homogeneous conditions; Based on the second water injection amount, the first water injection amount is determined.

6. The method according to claim 5, characterized in that The determining of the second water injection volume based on the cumulative water injection volumes respectively corresponding to the X water injection wells, the cumulative water production volumes respectively corresponding to the Y oil production wells, the first formation pressure, and the original formation pressure comprises: Based on the cumulative water injection volumes corresponding to the X water injection wells, the cumulative water production volumes corresponding to the Y oil production wells, the first formation pressure, and the original formation pressure, the second water injection volume is determined in the following manner: Wherein, IPV is the second water injection volume, Q j Q is the cumulative water injection volume corresponding to the jth water injection well among the X water injection wells. k is the cumulative water production corresponding to the kth oil production well among the Y oil production wells, P1 is the first formation pressure, and P2 is the original formation pressure.

7. The method according to claim 5, characterized in that The determining the first water injection amount based on the second water injection amount includes: Obtaining the formation pressures corresponding to the N water injection wells and the formation pressures corresponding to the M oil production wells; Determine a second formation pressure based on the formation pressures corresponding to the N water injection wells and the formation pressures corresponding to the M oil production wells, wherein the second formation pressure is used to indicate the comprehensive formation pressure level of the N water injection wells and the M oil production wells; The first water injection amount is determined based on the second water injection amount, the second formation pressure, and the original formation pressure.

8. The method according to claim 7, characterized in that The determining the first water injection amount based on the second water injection amount, the second formation pressure, and the original formation pressure includes: Based on the second water injection volume, the second formation pressure, and the original formation pressure, the first water injection volume is determined in the following manner: Q1=IPV*N*(P3-P2) Among them, Q1 is the first water injection volume, IPV is the second water injection volume, P3 is the second formation pressure, and P2 is the original formation pressure.

9. An oil reservoir water injection treatment device, characterized in that: include: A first acquisition module is used to acquire N water injection wells included in the target oil reservoir, and M oil production wells corresponding to the N water injection wells, wherein N is an integer greater than 0, and M is an integer greater than N; A first determination module is used to determine X water injection wells from the N water injection wells, and to determine the oil production wells corresponding to the X water injection wells from the M oil production wells, to obtain Y oil production wells, wherein X is an integer greater than 0 and less than N, and Y is an integer greater than X and less than M; The second acquisition module is used to acquire the cumulative water injection volume corresponding to the N water injection wells and the cumulative water production volume corresponding to the Y oil production wells; The second determination module is used to determine the effective utilization rate of water injection of the target oil reservoir based on the cumulative water injection volumes corresponding to the N water injection wells and the cumulative water production volumes corresponding to the Y oil production wells.

10. An electronic device, characterized in that: It comprises one or more processors and a memory, wherein the memory is used to store one or more programs, wherein when the one or more programs are executed by the one or more processors, the one or more processors implement the oil reservoir water injection treatment method according to any one of claims 1 to 8.

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