A carbonate rock well group water injection monitoring method, system, device and medium

Abstract

The application provides a carbonate rock well group water injection monitoring method, system, device and medium, comprising the following steps: drawing a pressure drop-accumulative liquid production curve corresponding to each pressure drop by using well group historical pressure measurement data points, and fitting a straight line relationship of the scattered points to obtain a ground crude oil elastic production rate; obtaining a daily formation pressure based on the ground crude oil elastic production rate; obtaining an underground elastic production based on the ground crude oil elastic production rate, obtaining a daily formation energy supplement value based on the underground elastic production, obtaining a daily lost formation energy based on the daily formation energy supplement value and the daily formation pressure, and obtaining a predicted formation pressure after water injection; taking a horizontal axis as time, taking the predicted formation pressure and water injection as main and auxiliary coordinates, establishing a well group water injection monitoring curve, comparing the predicted formation pressure with a measured formation pressure by using a scattered point of the measured formation pressure, and completing well group water injection monitoring; the application carries out real-time prediction of the formation pressure after water injection based on pressure measurement data before water injection, and accurately grasps the water injection state.

Description

TECHNICAL FIELD

[0001] The application belongs to the technical field of oil and gas reservoir development, and particularly relates to a carbonate rock well group water injection monitoring method, system, device and medium. BACKGROUND

[0002] At present, carbonate rock well group water injection is a new development technology, and with well pattern densification, the number of connected well groups increases, so dynamic monitoring and adjustment of well group water injection play an important role in water injection and production, but there is no related technology for developing well group water injection control by using material balance equation in the field of carbonate rock oil and gas field development, and at present, the well group water injection control only has parameters such as a general injection-production ratio, oil production intensity and water injection intensity, which cannot master the development trend of well group water injection and cannot achieve accurate control, and at present, only the experience of reservoir engineers is relied on to make qualitative judgments. SUMMARY

[0003] In view of the problems in the prior art, the application provides a carbonate rock well group water injection monitoring method, system, device and medium, which can use pressure measurement data before water injection to carry out real-time prediction of formation pressure after water injection, so as to accurately grasp the water injection state.

[0004] The application is realized by the following technical scheme:

[0005] A carbonate rock well group water injection monitoring method comprises the following steps:

[0006] A pressure drop-accumulative liquid production corresponding to each pressure drop relationship curve is drawn by using well group historical pressure measurement data points, and a straight line relationship of scattered points is fitted to obtain a ground crude oil elastic production rate; and daily formation pressures are obtained in turn based on the elastic production rate;

[0007] A B-P relationship curve is drawn based on the well PVT data volume coefficient and formation pressure scattered point graph;

[0008] Underground elastic production is obtained based on the elastic production rate of crude oil, daily formation energy supplement values are obtained based on the underground elastic production, daily lost formation energy is obtained based on the daily formation energy supplement values and daily formation pressures, and predicted formation pressures after water injection are obtained;

[0009] A curve is drawn daily, the horizontal axis is time, the predicted formation pressure and the water injection amount are main and vice coordinates, a well group water injection monitoring curve is established, the measured formation pressure is scattered, the predicted formation pressure and the measured formation pressure are compared, and well group water injection monitoring is completed.

[0010] Further, the daily formation pressures obtained in turn based on the elastic production rate are =Pq-Q / K;

[0011] Wherein, Pq is yesterday's formation pressure, Pq=Pi (original formation pressure) on the first day of production, Q is daily liquid production, and K is surface crude oil elastic production rate.

[0012] The daily formation pressure is obtained until the day before water injection of the well.

[0013] Further, the B-P relationship curve is: y=a*Pq+b, wherein a is a slope coefficient, Pq is yesterday's formation pressure, Pq=Pi on the first day of production, Pi is the original formation pressure, b is a straight line intercept, and y is the volume coefficient under the formation pressure state of Pq.

[0014] Further, the elastic production is:

[0015] Kw=K / ρo*y;

[0016] Wherein, Kw is the elastic production rate at the wellhead converted to the underground volume elastic production rate, and ρo is the surface crude oil density.

[0017] Further, the daily formation energy supplement value is: Iw*Bw / Kw.

[0018] Wherein, Iw is daily water injection volume, Bw is the volume coefficient of water, and Kw is the elastic production rate at the wellhead converted to the underground volume elastic production rate.

[0019] Further, the predicted formation pressure is Pq+Iw*Bw / Kw-Q / K, wherein Pq is yesterday's formation pressure, Pq=Pi (original formation pressure) on the first day of production, Iw is daily water injection volume, Bw is the volume coefficient of water, Kw is the elastic production rate at the wellhead converted to the underground volume elastic production rate, and K is the surface crude oil elastic production rate.

[0020] Further, the measured formation pressure is:

[0021]

[0022] Wherein, N is geological reserves, N P is stage cumulative oil production, B o is the volume coefficient under the stage cumulative oil production state, B oi is the original volume coefficient of crude oil; C t is a comprehensive compression coefficient; and △P is the original formation pressure-current formation pressure.

[0023] If the measured formation pressure is greater than the predicted formation pressure, the water injection intensity is too large, and the injection-production regression needs to be adjusted to return to a reasonable pressure, and if the measured formation pressure is less than the predicted formation pressure, the water injection intensity is increased.

[0024] A carbonate rock well group water injection monitoring system, comprising:

[0025] The preprocessing module is used to draw a curve showing the relationship between pressure drop and the cumulative liquid production corresponding to each pressure drop using historical pressure measurement data points of the well group, and to fit the scattered point straight line relationship to obtain the elastic yield of the surface crude oil. Based on the elastic yield, the daily formation pressure is then obtained.

[0026] The calculation module is used to draw a BP relationship curve based on the scatter plot of the volume coefficient and formation pressure of the well PVT data;

[0027] A prediction module is used to obtain an underground elastic yield based on the elastic yield of crude oil, obtain a daily formation energy replenishment value based on the underground elastic yield, obtain a daily formation energy loss based on the daily formation energy replenishment value and the daily formation pressure, and obtain a predicted formation pressure after water injection;

[0028] The judgment module is used to draw curves on a daily basis, with time as the horizontal axis and the predicted formation pressure and injection volume as the main and secondary coordinates. The well group water injection monitoring curve is established, the measured formation pressure is scattered, the predicted formation pressure is compared with the measured formation pressure, and the well group water injection monitoring is completed.

[0029] A computer device comprises a memory, a processor and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, the steps of a method for monitoring water injection in a carbonate well group are realized.

[0030] A computer-readable storage medium stores a computer program, which, when executed by a processor, implements the steps of a method for monitoring water injection in a carbonate well group.

[0031] Compared with the prior art, the present invention has the following beneficial technical effects:

[0032] The present invention provides a method, system, equipment and medium for monitoring water injection in a carbonate well group, comprising the following steps: using historical pressure measurement data points of the well group to draw a relationship curve between pressure drop and cumulative liquid production corresponding to each pressure drop, and fitting a scattered point straight line relationship to obtain a surface crude oil elastic yield. The present application adopts a scattered point fitting method to obtain a unified surface crude oil elastic yield under different circumstances, thereby allocating the influencing factors under various circumstances and obtaining a relatively accurate surface crude oil elastic yield as a whole; obtaining daily formation pressure based on the surface crude oil elastic yield; obtaining underground elastic production based on the surface crude oil elastic yield; obtaining daily formation energy replenishment value based on the underground elastic production; and obtaining daily formation energy replenishment value based on the daily formation energy replenishment value and daily formation energy replenishment value. The pressure is used to obtain the daily loss of formation energy and the predicted formation pressure after water injection; with the horizontal axis as time, the predicted formation pressure and injection volume are used as the main and secondary coordinates, a well group water injection monitoring curve is established, and the scatter points of the measured formation pressure are compared with the predicted formation pressure to complete the well group water injection monitoring. The water drive situation can be better reflected according to the predicted bottom pressure and the measured formation pressure. Compared with the existing technology, the present application can judge the water injection development trend in real time and achieve precise control based on specific values; the present application adopts the material balance equation and uses the pressure measurement data before water injection to carry out real-time prediction of the formation pressure after water injection, so as to accurately grasp the water injection status and provide guidance for well group water injection to relevant technical personnel in this field. BRIEF DESCRIPTION OF THE DRAWINGS

[0033] Figure 1 This is a flow chart of a carbonate well group water injection monitoring method according to the present invention;

[0034] Figure 2 A curve diagram showing the relationship between pressure drop and the cumulative liquid production corresponding to each pressure drop in a specific embodiment of the present invention;

[0035] Figure 3 BP relationship curve diagram in a specific embodiment of the present invention;

[0036] Figure 4 This is a water injection monitoring curve diagram of a well group in a specific embodiment of the present invention. DETAILED DESCRIPTION

[0037] The present invention will be further described in detail below with reference to specific embodiments, which are intended to explain the present invention rather than to limit it.

[0038] In order to enable those skilled in the art to better understand the solutions of the present invention, the technical solutions 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 embodiments described 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 making creative efforts should fall within the scope of protection of the present invention.

[0039] It should be noted that the terms "first", "second", etc. in the description 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 numbers used in this way can be interchanged 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.

[0040] The present invention provides a method for monitoring water injection in a carbonate well group. Figure 1 As shown, the following steps are included:

[0041] Using historical pressure measurement data points from the well group, a curve is drawn showing the relationship between pressure drop and the cumulative liquid production corresponding to each pressure drop. A scattered straight line is fitted to the relationship to obtain the surface crude oil elastic yield. The daily formation pressure is then obtained based on the surface crude oil elastic yield.

[0042] Based on the elastic yield of surface crude oil, the underground elastic yield is obtained; based on the underground elastic yield, the daily formation energy replenishment value is obtained; based on the daily formation energy replenishment value and the daily formation pressure, the daily lost formation energy is obtained; and the predicted formation pressure after water injection is obtained;

[0043] With time as the horizontal axis and predicted formation pressure and water injection volume as the main and secondary coordinates, a well group water injection monitoring curve is established. The predicted formation pressure and the measured formation pressure are compared at the scatter points of the measured formation pressure to complete the well group water injection monitoring.

[0044] Preferably, the daily formation pressure obtained based on the elastic yield is Pq-Q / K;

[0045] Where Pq is the formation pressure yesterday, Pq = Pi (original formation pressure) on the first day of production, Q is the daily liquid production, and K is the elastic yield of surface crude oil;

[0046] The daily formation pressure must be obtained up to the day before water injection of the well.

[0047] Preferably, the method further comprises making a BP relationship curve based on a scatter plot of the volume coefficient and formation pressure of the PVT data of the well, and establishing a relationship between the crude oil volume coefficient and the formation pressure to obtain the volume coefficient at each pressure value. The BP relationship curve is: y=a*Pq+b,

[0048] Where a is the slope coefficient, q is yesterday's formation pressure, Pq = Pi on the first day of production, Pi is the original formation pressure, b is the intercept of the straight line, and y is the volume coefficient under the Pq formation pressure state.

[0049] Preferably, the elastic yield is:

[0050] Kw=K / ρo*y;

[0051] Where Kw is the elastic yield at the wellhead converted to the underground volume elastic yield, and ρo is the density of crude oil.

[0052] Preferably, the daily formation energy replenishment value is: Iw*Bw / Kw;

[0053] Where Iw is the daily water injection volume, Bw is the volume coefficient of water, and Kw is the elastic yield at the wellhead converted to the underground volume elastic yield.

[0054] Preferably, the predicted formation pressure is Pq+Iw*Bw / Kw-Q / K, wherein Pq is yesterday's formation pressure, Pq=Pi (original formation pressure) on the first day of production, Iw is the daily water injection volume, Bw is the volume coefficient of water, Kw is the elastic yield of the wellhead converted to the underground volume elastic yield, Q is the daily liquid production, and K is the elastic yield of the surface crude oil.

[0055] Preferably, the measured formation pressure is:

[0056]

[0057] Among them, N is geological reserves, N P is the cumulative oil production in the stage, B o is the volume coefficient under the cumulative oil production state, B oi is the original volume coefficient of crude oil; C t is the comprehensive compression coefficient; △P is the original formation pressure minus the current formation pressure;

[0058] If the measured formation pressure is greater than the predicted formation pressure, the water injection intensity is too high and the injection-production ratio needs to be adjusted back to a reasonable pressure. If the measured formation pressure is less than the predicted formation pressure, the water injection intensity should be increased.

[0059] Specifically, it is currently believed that the best approach for the measured formation pressure is to be close to the predicted formation pressure. Therefore, we can use the measured formation static pressure to scatter points on the monitoring curve. If it is higher than the curve, it indicates that the water injection intensity is too high and the injection-production ratio needs to be adjusted to return to a reasonable pressure. If it is lower than the predicted curve, energy needs to be added.

[0060] If long-term water injection with an unreasonable injection-production ratio results in the measured formation pressure being much higher than the predicted formation pressure, there is a risk of water breakthrough, and some dynamic reserves will be lost. However, due to the low water content, the dynamic reserves cannot be calculated using the Type C curve. Kw = K / ρo*y can be used to reversely calculate K so that Pq calculated from K is equal to the measured formation pressure. The material balance equation can then be used to calculate the dynamic reserves N' after water injection, and the dynamic reserve loss △N = N-N'. It should be noted that those skilled in the art can use this curve to set the injection amount for different stages and different oil production intensities.

[0061] Example 1:

[0062] Take a well group in Fuman Oilfield as an example:

[0063] (1) Draw the relationship curve of △P-Np, that is, the relationship curve of pressure drop-cumulative liquid production corresponding to each pressure drop; the data of pressure drop and cumulative liquid production corresponding to each pressure drop are shown in Table 1:

[0064] Table 1

[0065]

[0066]

[0067] Fitting a scattered straight line relationship, such as Figure 2 As shown in Table 2, the elastic yield K = 3998.2 is obtained; (2) the predicted formation pressure is calculated as shown in Table 2:

[0068] Table 2

[0069]

[0070] (3) Calculate the relationship between the compression coefficient and the formation pressure, as shown in Table 3:

[0071] Table 3

[0072]

[0073]

[0074] like Figure 3 As shown, the BP relationship curve obtained is y = -0.0033 + 1.7707;

[0075] (4) Calculate Kw = K / ρo*(y = a*Pq+b) = 3998 / 0.82*(-0.0033*Pq+1.7707). This value varies with the formation pressure. On the first day of water injection, Pq = 44.797 MPa.

[0076] Iw=Iw*1.05 / Kw,

[0077] Pb=Pq+Iw*1.05 / Kw-Q / K,

[0078] Table 3

[0079]

[0080] The collected data in this embodiment, as shown in Table 3, is used to calculate the daily lost formation energy, predicted formation pressure, actual formation pressure, and diffuse energy after water injection;

[0081] Iw=Daily water injection*1.05 / Kw

[0082] Pb=Pq+daily water injection*1.05 / Kw-Q / K

[0083] (5) Draw a curve on a daily basis, with the horizontal axis representing time, the vertical axis representing the primary coordinate of the formation pressure, and the secondary coordinate representing the injection volume (the primary and secondary coordinates can be adjusted). Then, scatter the measured formation pressure points. At this point, the well group water injection monitoring curve is completed.

[0084] (6) According to the above figure, Figure 4 As shown in the figure, the measured formation pressure is significantly higher than the predicted curve, necessitating appropriate reduction. Therefore, Well 1 is switched to production, gradually returning to a reasonable formation pressure. Using relevant parameters, the pre-waterflood geological reserves (N) are calculated as N = 3960 * 1.6235 / 1.4839 / 16.6941 = 2.563 million tons. K' is then calculated back from K, so that the formation pressure calculated using K' equals the most recently measured formation pressure. The calculated K' is 2950, ​​N' = 2950 * 1.6235 / 1.4839 / 16.6941 = 1.933 million tons, and ΔN = N - N' = 630,000 tons. Based on a 15% recovery factor, the estimated additional crude oil production is 63 * 0.15 = 94,500 tons.

[0085] The present invention provides a carbonate well group water injection monitoring system, comprising:

[0086] The preprocessing module is used to draw a curve showing the relationship between pressure drop and the cumulative liquid production corresponding to each pressure drop using historical pressure measurement data points of the well group, and to fit the scattered point straight line relationship to obtain the elastic yield of the surface crude oil. Based on the elastic yield, the daily formation pressure is then obtained.

[0087] A prediction module, configured to obtain an underground elastic yield based on the surface elastic yield of crude oil, obtain a daily formation energy replenishment value based on the underground elastic yield, obtain a daily formation energy loss based on the daily formation energy replenishment value and the daily formation pressure, and obtain a predicted formation pressure after water injection;

[0088] The judgment module is used to draw curves on a daily basis, with time as the horizontal axis and the predicted formation pressure and injection volume as the main and secondary coordinates. The well group water injection monitoring curve is established, the measured formation pressure is scattered, the predicted formation pressure is compared with the measured formation pressure, and the well group water injection monitoring is completed.

[0089] In another embodiment of the present invention, a computer device is provided, comprising a processor and a memory, wherein the memory is used to store a computer program, wherein the computer program includes program instructions, and the processor is used to execute the program instructions stored in the computer storage medium. The processor may be a central processing unit (CPU), or may be other general-purpose processors, digital signal processors (DSP), application-specific integrated circuits (ASIC), field-programmable gate arrays (FPGA), or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc. It is the computing core and control core of the terminal, which is suitable for implementing one or more instructions, specifically suitable for loading and executing one or more instructions in the computer storage medium to implement the corresponding method flow or corresponding function; the processor described in the embodiment of the present invention can be used for the operation of a carbonate well group water injection monitoring method.

[0090] In another embodiment of the present invention, a storage medium is provided, specifically a computer-readable storage medium (Memory). The computer-readable storage medium is a memory device in a computer device, used to store programs and data. It is understood that the computer-readable storage medium herein may include both built-in storage media in the computer device and, of course, extended storage media supported by the computer device. The computer-readable storage medium provides storage space, which stores the terminal's operating system. Furthermore, the storage space also stores one or more instructions suitable for being loaded and executed by a processor. These instructions may be one or more computer programs (including program code). It should be noted that the computer-readable storage medium herein may be a high-speed RAM memory or a non-volatile memory, such as at least one disk storage device. The processor may load and execute the one or more instructions stored in the computer-readable storage medium to implement the corresponding steps of the carbonate well group water injection monitoring method described in the above embodiment.

[0091] It will be understood by those skilled in the art that embodiments of the present invention may be provided as methods, systems, or computer program products. Thus, the present invention may take the form of an entirely hardware embodiment, an entirely software embodiment, or an embodiment combining software and hardware. Furthermore, the present invention may take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to magnetic disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0092] The present invention is described with reference to flowcharts and / or block diagrams of methods, devices (systems), and computer program products according to embodiments of the present invention. It should be understood that each process and / or block in the flowcharts and / or block diagrams, as well as combinations of processes and / or blocks in the flowcharts and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing device to produce a machine, so that the instructions executed by the processor of the computer or other programmable data processing device generate instructions for implementing the processes in the flowcharts and / or block diagrams. Figure 1 a process or multiple processes and / or boxes Figure 1 A device that provides the functions specified in a block or multiple blocks.

[0093] These computer program instructions may also be stored in a computer readable memory that can direct a computer or other programmable data processing device to work in a specific manner, so that the instructions stored in the computer readable memory produce an article of manufacture comprising an instruction device, which implements the process Figure 1 a process or multiple processes and / or boxes Figure 1 The function specified in one or more boxes.

[0094] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operational steps are executed on the computer or other programmable device to produce a computer-implemented process, thereby providing the instructions executed on the computer or other programmable device for implementing the process. Figure 1 a process or multiple processes and / or boxes Figure 1 The steps for the function specified in one or more boxes.

[0095] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention, rather than to limit it. Although the present invention has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the aforementioned embodiments, or replace some or all of the technical features therein with equivalents. However, these modifications or replacements do not cause the essence of the corresponding technical solutions to deviate from the scope of the technical solutions of the embodiments of the present invention.

Claims

1. A method for monitoring water injection in a carbonate well group, characterized in that: The following steps are involved: The relationship curve between pressure drop and cumulative liquid production corresponding to each pressure drop is drawn using the historical pressure measurement data points of the well group, and the scattered straight line relationship is fitted to obtain the elastic yield of the surface crude oil. Daily formation pressure is obtained based on the elastic yield of surface crude oil; The underground elastic production is obtained based on the elastic yield of the surface crude oil, the daily formation energy replenishment value is obtained based on the underground elastic production, the daily formation energy loss is obtained based on the daily formation energy replenishment value and the daily formation pressure, and the predicted formation pressure after water injection is obtained; With time as the horizontal axis, the predicted formation pressure and water injection volume are the primary and secondary coordinates, and a well group water injection monitoring curve is established. The predicted formation pressure and the measured formation pressure are compared at the scattered points to complete the well group water injection monitoring; The daily formation pressure obtained based on the elastic yield of the surface crude oil is = Pq-Q / K; Where Pq is the formation pressure yesterday, Pq=Pi on the first day of production, Pi is the original formation pressure, Q is the daily liquid production, and K is the elastic yield of surface crude oil; The daily formation pressure must be obtained up to the day before water injection of the well group; The predicted formation pressure is Pq+Iw*Bw / Kw-Q / K, where Pq is the formation pressure yesterday, Pq=Pi (original formation pressure) on the first day of production, Iw is the daily water injection volume, Bw is the volume coefficient of water, Kw is the elastic yield at the wellhead converted to the underground volume elastic yield, and K is the elastic yield of the surface crude oil.

2. A carbonate well group water injection monitoring method according to claim 1, characterized in that: It also includes drawing a BP relationship curve based on a scatter plot of the volume coefficient and formation pressure of the PVT data of the well group, establishing a relationship between the crude oil volume coefficient and the formation pressure, and obtaining the volume coefficient at each pressure value. The BP relationship curve is: y=a*Pq+b, where a is the slope coefficient, Pq is yesterday's formation pressure, Pq=Pi on the first day of production, Pi is the original formation pressure, b is the straight line intercept, and y is the volume coefficient under the Pq formation pressure state.

3. A carbonate well group water injection monitoring method according to claim 2, characterized in that: The elastic output is: Kw=K / ρo*y; Where Kw is the elastic yield at the wellhead converted to the underground volume elastic yield, and ρo is the density of crude oil on the ground.

4. A carbonate well group water injection monitoring method according to claim 1, characterized in that: The daily formation energy replenishment value is: Iw*Bw / Kw; Where Iw is the daily water injection volume, Bw is the volume coefficient of water, and Kw is the elastic yield at the wellhead converted to the underground volume elastic yield.

5. The method for monitoring water injection in a carbonate well group according to claim 1, characterized in that: The measured formation pressure is: ； Among them, N is geological reserves, N P is the cumulative oil production in the stage, B o is the volume coefficient under the cumulative oil production state, B oi is the original volume coefficient of crude oil; C t is the comprehensive compression coefficient; △P is the original formation pressure minus the current formation pressure; If the measured formation pressure is greater than the predicted formation pressure, the water injection intensity is too high and the injection-production ratio needs to be adjusted to return to a reasonable pressure. If the measured formation pressure is less than the predicted formation pressure, the water injection intensity should be increased.

6. A carbonate well group water injection monitoring system, characterized in that: A method for monitoring water injection in a carbonate well group according to any one of claims 1 to 5, comprising: The preprocessing module is used to draw a curve showing the relationship between pressure drop and the cumulative liquid production corresponding to each pressure drop using historical pressure measurement data points of the well group, and to fit the scattered point straight line relationship to obtain the elastic yield. Based on the elastic yield, the daily formation pressure is then obtained. A prediction module is used to obtain an underground elastic yield based on the elastic yield of crude oil, obtain a daily formation energy replenishment value based on the underground elastic yield, obtain a daily formation energy loss based on the daily formation energy replenishment value and the daily formation pressure, and obtain a predicted formation pressure after water injection; The judgment module is used to draw a daily curve with time as the horizontal axis and the predicted formation pressure and water injection volume as the main and secondary coordinates, establish a well group water injection monitoring curve, and scatter the measured formation pressure points to compare the predicted formation pressure with the measured formation pressure to complete the well group water injection monitoring; The daily formation pressure obtained based on the elastic yield of the surface crude oil is = Pq-Q / K; Where Pq is the formation pressure yesterday, Pq = Pi (original formation pressure) on the first day of production, Q is the daily liquid production, and K is the elastic yield of surface crude oil; The daily formation pressure must be obtained up to the day before water injection of the well group; The predicted formation pressure is Pq+Iw*Bw / Kw-Q / K, where Pq is the formation pressure yesterday, Pq=Pi (original formation pressure) on the first day of production, Iw is the daily water injection volume, Bw is the volume coefficient of water, Kw is the elastic yield at the wellhead converted to the underground volume elastic yield, and K is the elastic yield of the surface crude oil.

7. A computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein: When the processor executes the computer program, the steps of the method for monitoring water injection in a carbonate well group as described in any one of claims 1 to 5 are implemented.

8. A computer-readable storage medium storing a computer program, characterized in that: When the computer program is executed by a processor, the steps of the method for monitoring water injection in a carbonate well group as described in any one of claims 1 to 5 are implemented.

Images