An oilfield water injection working condition automatic identification method, system, device and storage medium

Abstract

The present application belongs to oil field oil production process technical field, and relates to a kind of oil field water injection working condition automatic identification method, comprising: obtaining the valve group water separator pressure of injection well, water well pipe pressure, injection allocation;According to injection allocation, if there is injection not or under injection, then compare the valve group water separator pressure and water well pipe pressure;If valve group water separator pressure is greater than injection well pipe pressure plus preset fluctuation pressure, then judge instrument fault or injection rate problem;If valve group water separator pressure compared to average pressure drops, and pipe pressure is in preset fluctuation range, then it is injection station or trunk problem leading to pressure drop injection not;If pipe pressure compared to average pressure rises, and valve group water separator pressure meets preset fluctuation range, then obtain recent preset time data, if injection not or corresponding oil well production drops, then determine reservoir poor injection not;If not injection not in recent preset time range, then it is water nozzle blockage, wellbore pollution or water quality problem.

Description

Technical Field

[0001] This invention belongs to the field of oilfield production technology, specifically relating to an automatic identification method, system, equipment, and storage medium for oilfield water injection conditions. Background Technology

[0002] Monitoring and analyzing the water injection process are the most important daily technical management tasks for water injection wells, and also serve as a "barometer" for judging whether a water injection well is operating normally. Utilizing the Internet of Things (IoT) to achieve monitoring and intelligent analysis of the water injection well's operating process is an important direction for the development of oilfield water injection management.

[0003] Currently, online monitoring of water injection wells has been implemented in most oilfields in China. However, the detailed identification and classification of conditions where water injection fails to proceed still mainly relies on technicians using collected data such as flow rate, pressure, and other reports for assessment. Based on the assessment results, relevant measures are then formulated. Because the assessment process is quite cumbersome and involves a large number of water injection wells, the workload is substantial, which cannot effectively meet the work pace and is detrimental to improving work efficiency. Summary of the Invention

[0004] The purpose of this invention is to provide an automatic identification method, system, equipment, and storage medium for oilfield water injection conditions, which solves the problems of current manual judgment, large workload, and low work efficiency.

[0005] This invention is achieved through the following technical solution:

[0006] An automatic identification method for water injection conditions in oilfields includes the following steps:

[0007] S1. Obtain the pressure of the valve group water injector, the water well pipe pressure, and the injection volume of the water injection well;

[0008] S2. Determine if the water injection well is open. If it is open, proceed to S3.

[0009] S3. Determine whether there is insufficient or inadequate injection in the well based on the injection volume. If there is insufficient or inadequate injection, proceed to S4.

[0010] S4. Compare the pressure of the valve group water separator with the pressure in the well pipe:

[0011] If the pressure of the valve group water purifier is greater than the sum of the injection well pipe pressure and the preset fluctuation pressure, then it is determined that there is an instrument malfunction or a problem with the water injection rate.

[0012] If the pressure of the valve group water purifier does not exceed the sum of the preset fluctuation pressure of the injection well pipe, then proceed to S5;

[0013] S5. Determine the magnitude of the decrease or increase in valve group water pressure, pipe pressure, and average value:

[0014] If the pressure of the valve group water separator drops by more than x% compared to the average pressure of the water separator, and the pipe pressure is within the preset fluctuation range, then the pressure drop and inability to inject water is caused by a problem with the water injection station or the main line.

[0015] If the pipe pressure increases by more than y% compared to the average pipe pressure, and the pressure of the valve group water purifier meets the preset fluctuation range, then the problem is judged to be at the water injection station or upstream of the main line.

[0016] S6. Obtain data from the recent preset time. If the oil cannot be injected or the production of the corresponding oil well decreases, it is determined that the reservoir is poor and cannot be injected. Otherwise, proceed to S7.

[0017] S7. If the water cannot be injected within the preset time range, it is determined that the water nozzle is blocked, the well is contaminated, or there is a problem with the water quality.

[0018] Furthermore, in S2, the well is determined to be open by checking whether the injection volume is 0. If the injection volume is 0, the well is closed; if it is not 0, the well is open.

[0019] Furthermore, in S3, the injection volume is used to determine whether the well has insufficient or inadequate injection. If insufficient or inadequate injection is found, the specific details are as follows:

[0020] When the injection volume is ≤20m 3 ,and Then there is a shortfall;

[0021] When the injection volume is ≥20m 3 ,and Then there is a shortfall.

[0022] Furthermore, in S4, the preset fluctuation pressure is 0.2-0.6 MPa.

[0023] Furthermore, in S5, the preset fluctuation range is 0-0.6 MPa.

[0024] Furthermore, in S5, the instantaneous values ​​of pump start-up and shutdown, as well as other sudden instantaneous values, are removed during the calculation of the average pressure value.

[0025] Furthermore, in S5, the value of x ranges from 8% to 20%;

[0026] In S6, the value of y ranges from 8% to 20%;

[0027] In S6, the recent preset time is the next 3 months.

[0028] This invention also discloses an automatic analysis and identification system for the causes of under-injection in water injection wells, comprising:

[0029] The data acquisition module is used to acquire the pressure of the valve group water separator, the water well pipe pressure, and the injection volume of the water injection well;

[0030] The well opening judgment module is used to determine whether the injection well has been opened. If the well has been opened, the under-injection judgment module is activated.

[0031] The under-injection judgment module is used to determine whether there is a situation of insufficient injection or under-injection in the well based on the injection volume. If there is a situation of insufficient injection or under-injection, the instrument fault judgment module is activated.

[0032] The instrument fault diagnosis module is used to compare the pressure of the valve group water separator with the pressure of the well pipe;

[0033] If the pressure of the valve group water separator is greater than the sum of the injection well pipe pressure and the preset fluctuation pressure, then the instrument is considered faulty.

[0034] If the pressure of the valve group water separator does not exceed the sum of the injection well pipe pressure and the preset fluctuation pressure, then proceed to S5;

[0035] The water injection station fault diagnosis module is used to determine the magnitude of decrease or increase in partial pressure, pipe pressure, and average value.

[0036] If the average pressure drop by more than x%, and the pipe pressure remains unchanged, then the problem is caused by a problem with the water injection station or main line, resulting in a pressure drop that prevents injection.

[0037] If the average pipe pressure rises by more than y%, and the pressure of the valve group water purifier meets the preset fluctuation range, then the problem is identified as a problem at the water injection station or upstream of the main line.

[0038] The reservoir judgment module is used to obtain data from the recent preset time. If injection fails and the corresponding well production and formation pressure decrease, it is judged as poor reservoir that cannot be injected.

[0039] If the water cannot be injected within a recently preset time frame, it is determined that the water nozzle is clogged, the well is contaminated, or there is a problem with the water quality.

[0040] The present invention also discloses a computer device, including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the steps of the automatic identification method based on oilfield water injection conditions.

[0041] The present invention also discloses a computer-readable storage medium storing a computer program, which, when executed by a processor, implements the steps of the automatic identification method for oilfield water injection conditions.

[0042] Compared with the prior art, the present invention has the following beneficial technical effects:

[0043] This invention discloses an automatic identification method for water injection conditions in oilfields. Utilizing collected data such as injection valve component pressure, injection well tubing pressure (oil pressure), and injection volume, the method categorizes and alarms the conditions of insufficient or no water injection in injection wells. This method enables real-time identification of conditions such as insufficient or no water injection in injection wells and categorizes the causes, providing intuitive guidance for technicians. It allows for quick location of the specific reasons for insufficient or no water injection in injection wells, enabling the implementation of corrective measures to improve on-site work efficiency and better assist employees in ensuring sufficient water injection.

[0044] This invention can use collected data to identify and classify the operating conditions of water injection wells in real time, providing decision-making basis for managers. Water injection in oilfields is of great value to oilfield development and can effectively maintain formation energy. This invention can effectively detect wells with insufficient water injection, providing a powerful tool for maintaining sufficient water injection in oilfields. With the expansion of oilfield exploitation, the problem of too many wells and too few personnel has become increasingly prominent. Through this invention, one person can manage multiple wells, which is of great significance for realizing unmanned operation of stations.

[0045] This invention also discloses a computer device or storage medium. Traditional methods of determining the causes of water injection well failure and under-injection require manual sorting and classification, involving on-site inspection of relevant instruments and data, and then identification based on experience. Embedding this method into a computer system allows existing systems to directly utilize this method to achieve intelligent computer-based classification and identification, replacing the original manual identification process. Attached Figure Description

[0046] Figure 1 This is a flowchart of an automatic identification method for oilfield water injection conditions according to the present invention;

[0047] Figure 2 This is a schematic diagram of an automatic identification system for oilfield water injection conditions according to the present invention. Detailed Implementation

[0048] To make the objectives, technical solutions, and advantages of the present invention clearer, the following detailed description is provided in conjunction with the accompanying drawings and embodiments. It should be understood that the specific embodiments described herein are merely illustrative of the invention and are not intended to limit the invention; that is, the described embodiments are only a part of the embodiments of the present invention, and not all of them.

[0049] The components described and illustrated in the accompanying drawings and embodiments of this invention can be arranged and designed in various different configurations. Therefore, the detailed description of the embodiments of the invention provided in the following drawings is not intended to limit the scope of the claimed invention, but merely to illustrate one selected embodiment of the invention. All other embodiments obtained by those skilled in the art based on the accompanying drawings and embodiments of this invention without inventive effort are within the scope of protection of this invention.

[0050] It should be noted that the terms “comprising,” “including,” or any other variations are intended to cover non-exclusive inclusion, such that a process, element, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to the process, element, method, article, or apparatus.

[0051] The features and performance of the present invention will be further described in detail below with reference to embodiments.

[0052] This method mainly analyzes whether water injection wells in oil fields are under-injected, unable to inject water, and the specific reasons related to these issues.

[0053] When implementing this method, the algorithm can be embedded into an oilfield water injection monitoring system.

[0054] Step 1: First, extract the water injection well valve group water unit pressure P1, water well pipe pressure (oil pressure) P0, and injection volume V1 from the oilfield water injection monitoring system.

[0055] The second step is to determine whether the injection well is open by judging whether the injection volume V1 is greater than 0, thus eliminating the possibility of insufficient or no injection caused by well shut-in.

[0056] If the injection volume is not 0, then the well is considered to be open, and the analysis continues.

[0057] If the injection volume is 0, then shut in the well and the process ends.

[0058] Step 3: Determine if the well has issues with insufficient or no injection. The specific determination method is as follows:

[0059] 1. Injection volume ≤ 20m 3 ; Then there is a shortfall;

[0060] 2. Injection volume > 20m 3 ; Then there is a shortfall;

[0061] If the conditions are met, it is determined that the injection well is not injecting water or is under-injected. Further analysis is conducted to distinguish whether the problem is a malfunction of the water injection control instrument, a problem with the water injection station or main pipeline, a water quality problem, or a reservoir problem.

[0062] If the conditions are not met, then the injection well does not have the problem of insufficient or inadequate injection, and the process ends.

[0063] Step 4: Determine if the pressure of the valve group water separator is greater than the sum of the injection well pipe pressure and the preset fluctuation pressure.

[0064] If the value is greater than the specified value, the system will push a check for issues with the instrument or water injection rate, and the process will end; if the condition is not met, the analysis will continue.

[0065] The preset fluctuation pressure is generally set to 0.2-0.6 MPa.

[0066] Step 5: Determine the magnitude of the decrease or increase in the valve group water pressure, pipe pressure, and average value.

[0067] If the pressure of the valve group water separator drops by more than x% compared to the average value, and the pipe pressure does not change significantly, then the pressure drop and inability to inject water is caused by upstream issues such as the water injection station or main line.

[0068] That is: ΔP(1-x%) > P1, and the pipe pressure change is within the range of P0±z.

[0069] If the pressure of the valve group water separator drops by more than x% compared to the average pressure, and the pipe pressure rises by more than y% compared to the average pipe pressure, and the pressure of the valve group water separator meets the preset fluctuation range, then the problem lies with the water injection station or upstream of the main pipeline.

[0070] That is: ΔP(1-x%)>P1, P0>ΔP0(1+y%).

[0071] Wherein, ΔP is the average partial pressure, which is the average pressure of the valve group water separator over the past 30 days, ΔP0 is the average pipe pressure over the past 30 days. When calculating the average value, the start-up and shutdown data of the pump and the bad points need to be removed. P1 is the pressure of the valve group water separator, P0 is the pipe pressure, x and y are taken as 8%-20%, and z is taken as 0-0.6Mpa.

[0072] Step 6: If the pipe pressure increases by more than y% compared to the average value, the pressure of the valve group water separator does not change significantly.

[0073] That is: P0 > ΔP0(1+y%), and the pressure change of the valve group water separator is within the range of P1±z.

[0074] Then extract the water injection well data, corresponding oil production data, oil production data, and reservoir data for the past 3 months. If water cannot be injected, that is, if the injection volume is less than 60% of the allocated volume V1, or if the production of the corresponding oil well decreases, it is determined that the reservoir is poor and cannot be injected.

[0075] Wherein, ΔP0 is the average pipe pressure over the past 30 days. When calculating the average pipe pressure, data on pump start-up / shutdown and faulty points need to be removed. P0 is the pipe pressure, y is taken as 8%-20%, and z is taken as 0-0.6 MPa.

[0076] Step 7: If it is not that the injection cannot be made at all, that is, more than 60% of the injection volume V1, then it is determined that the inability to inject or insufficient injection is caused by problems such as water nozzle blockage, well barrel pollution, or water quality.

[0077] The above threshold values ​​for variation z can be adjusted according to different oilfields.

[0078] This invention also discloses an automatic analysis and identification system for the causes of under-injection in water injection wells, comprising:

[0079] The data acquisition module is used to acquire the pressure of the valve group water separator, the water well pipe pressure, and the injection volume of the water injection well;

[0080] The well opening judgment module is used to determine whether the injection well has been opened. If the well has been opened, the under-injection judgment module is activated.

[0081] The under-injection judgment module is used to determine whether there is a situation of insufficient injection or under-injection in the well based on the injection volume. If there is a situation of insufficient injection or under-injection, the instrument fault judgment module is activated.

[0082] The instrument fault diagnosis module is used to compare the pressure of the valve group water separator with the pressure of the well pipe;

[0083] If the pressure of the valve group water separator is greater than the sum of the injection well pipe pressure and the preset fluctuation pressure, then the instrument is considered faulty.

[0084] If the pressure of the valve group water separator does not exceed the sum of the injection well pipe pressure and the preset fluctuation pressure, then proceed to S5;

[0085] The water injection station fault diagnosis module is used to determine the magnitude of decrease or increase in partial pressure, pipe pressure, and average value.

[0086] If the average pressure drop by more than x%, and the pipe pressure remains unchanged, then the problem is caused by a problem with the water injection station or main line, resulting in a pressure drop that prevents injection.

[0087] If the average pipe pressure increases by more than y%, and the partial pressure meets the preset fluctuation range, then the reservoir judgment module is activated.

[0088] The reservoir judgment module is used to obtain data from the recent preset time. If injection fails and the corresponding well production and formation pressure decrease, it is judged as poor reservoir that cannot be injected.

[0089] If the water supply has not been consistently unavailable recently, then the problem is likely due to a clogged faucet, contaminated well shaft, or water quality issues.

[0090] This invention uses real-time data collection of injection wellhead pressure, flow rate, and various data from the corresponding oil wells and formation data to determine the operating conditions of injection wells. It analyzes the causes of insufficient or no water injection and classifies the results in the early warning system according to the different causes of insufficient water injection. This allows technicians to quickly grasp the dynamics of injection wells and formulate relevant remedial measures based on the classification results, thereby improving work efficiency and the level of intelligent management in oilfields.

[0091] The automatic identification method for oilfield water injection conditions of the present invention can be implemented in a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the present invention can be implemented as a computer program product on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0092] If the automatic identification method for oilfield water injection conditions of the present invention is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, all or part of the processes in the methods of the above embodiments of the present invention can also be implemented by a computer program instructing related hardware. The computer program can be stored in a computer-readable storage medium, and when executed by a processor, it can implement the steps of the various method embodiments described above. The computer program includes computer program code, which can be in the form of source code, object code, executable files, or certain intermediate forms. The computer-readable storage medium includes permanent and non-permanent, removable and non-removable media, and information storage can be implemented by any method or technology. Information can be computer-readable instructions, data structures, program modules, or other data. It should be noted that the content contained in the computer-readable medium can be appropriately added or subtracted according to the requirements of legislation and patent practice in the jurisdiction. For example, in some jurisdictions, according to legislation and patent practice, computer-readable media do not include electrical carrier signals and telecommunication signals. The computer storage medium can be any available medium or data storage device that a computer can access, including but not limited to magnetic storage (e.g., floppy disk, hard disk, magnetic tape, magneto-optical disk (MO)), optical storage (e.g., CD, DVD, BD, HVD), and semiconductor storage (e.g., ROM, EPROM, EEPROM, non-volatile memory (NAND FLASH), solid-state drive (SSD)).

[0093] In an exemplary embodiment, a computer device is also provided, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, it implements the steps of the automatic identification method for oilfield water injection conditions. The processor may be a Central Processing Unit (CPU), or it may be other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), field-programmable gate arrays (FPGAs), or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc.

[0094] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention and not to limit it. Although the present invention has been described in detail with reference to the above embodiments, those skilled in the art should understand that modifications or equivalent substitutions can still be made to the specific implementation of the present invention. Any modifications or equivalent substitutions that do not depart from the spirit and scope of the present invention should be covered within the scope of protection of the claims of the present invention.

Claims

1. An automatic identification method for water injection conditions in oilfields, characterized in that, Includes the following steps: S1. Obtain the pressure of the valve group water injector, the water well pipe pressure, and the injection volume of the water injection well; S2. Determine if the water injection well is open. If it is open, proceed to S3. S3. Determine whether there is under-injection in the well based on the injection volume. If there is under-injection, proceed to S4. S4. Compare the pressure of the valve group water separator with the pressure in the well pipe: If the pressure of the valve group water purifier is greater than the sum of the injection well pipe pressure and the preset fluctuation pressure, then it is determined that there is an instrument malfunction or a problem with the water injection rate. If the pressure of the valve group water purifier does not exceed the sum of the preset fluctuation pressure of the injection well pipe, then proceed to S5; S5. Determine the magnitude of the decrease or increase in valve group water pressure, pipe pressure, and average value: If the pressure of the valve group water separator drops by more than x% compared to the average pressure of the water separator, and the pipe pressure is within the preset fluctuation range, then the problem is caused by a problem with the water injection station or the main line, resulting in a pressure drop and inability to inject water. If the pipe pressure increases by more than y% compared to the average pipe pressure, and the pressure of the valve group water purifier meets the preset fluctuation range, then the problem is judged to be at the water injection station or upstream of the main line. S6. Obtain data from the recent preset time. If the oil cannot be injected or the production of the corresponding oil well decreases, it is determined that the reservoir is poor and cannot be injected. Otherwise, proceed to S7. S7. If the water cannot be injected within the preset time range, it is determined that the water nozzle is blocked, the well is contaminated, or there is a problem with the water quality. In S3, the injection volume is used to determine whether the well is under-injected. If under-injection exists, the specific steps are as follows: When the injection volume is ≤20m 3 ,and If the percentage is greater than 15%, then the bet is underpaid. When the injection volume is >20m 3 ,and If the percentage is greater than 10%, then the bet is underpaid. In S5, the instantaneous values ​​of pump start-up and shutdown, as well as other sudden instantaneous values, are removed during the calculation of the average pressure value. In S6, the recent preset time is the next 3 months.

2. The automatic identification method for oilfield water injection conditions according to claim 1, characterized in that, In S2, the well is determined to be open or closed by checking if the injection volume is 0. If the injection volume is 0, the well is closed; if it is not 0, the well is open.

3. The automatic identification method for oilfield water injection conditions according to claim 1, characterized in that, In S4, the preset fluctuation pressure is 0.2-0.6 MPa.

4. The automatic identification method for oilfield water injection conditions according to claim 1, characterized in that, In S5, the preset fluctuation range is 0-0.6MPa.

5. The method for automatic identification of water injection conditions in oilfields according to claim 1, characterized in that, In S5, the value of x% ranges from 8% to 20%; In S6, the value of y% ranges from 8% to 20%.

6. An automatic analysis and identification system for the causes of under-injection in water injection wells, used to implement the automatic identification method for oilfield water injection conditions as described in any one of claims 1-5, characterized in that, include: The data acquisition module is used to acquire the pressure of the valve group water separator, the water well pipe pressure, and the injection volume of the water injection well; The well opening judgment module is used to determine whether the injection well has been opened. If the well has been opened, the under-injection judgment module is activated. The under-injection judgment module is used to determine whether there is a situation of insufficient injection or under-injection in the well based on the injection volume. If there is a situation of insufficient injection or under-injection, the instrument fault judgment module is activated. The instrument fault diagnosis module is used to compare the pressure of the valve group water separator with the pressure of the well pipe; If the pressure of the valve group water separator is greater than the sum of the injection well pipe pressure and the preset fluctuation pressure, then the instrument is considered faulty. If the pressure of the valve group water separator does not exceed the sum of the injection well pipe pressure and the preset fluctuation pressure, then proceed to S5; The water injection station fault diagnosis module is used to determine the magnitude of decrease or increase in valve group water pressure, pipe pressure, and average value. If the pressure of the valve group water purifier drops by more than x% compared to the average value, and the pipe pressure remains unchanged, then the problem is caused by a problem with the water injection station or main line, resulting in a pressure drop and inability to inject water. If the average pipe pressure rises by more than y%, and the pressure of the valve group water purifier meets the preset fluctuation range, then the problem is identified as a problem at the water injection station or upstream of the main line. The reservoir judgment module is used to obtain data from the recent preset time. If injection fails and the corresponding well production and formation pressure decrease, it is judged as poor reservoir that cannot be injected. If the water cannot be injected within a recently preset time frame, it is determined that the water nozzle is clogged, the well is contaminated, or there is a problem with the water quality.

7. A computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the steps of the automatic identification method for oilfield water injection conditions as described in any one of claims 1 to 5.

8. A computer-readable storage medium storing a computer program, characterized in that, When the computer program is executed by the processor, it implements the steps of the automatic identification method for oilfield water injection conditions as described in any one of claims 1 to 5.

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