Determination method and device for management and control strategy of sealed wellbore, storage medium, electronic device and computer program product

Abstract

The invention discloses a determination method and device of a sealed wellbore management and control strategy, a storage medium, an electronic device and a computer program product, and relates to the field of sealed wellbore management and control, and the determination method of the sealed wellbore management and control strategy comprises the steps of monitoring operation data of a target wellbore, the operation data at least comprise the well killing fluid return condition of a diversion trench outlet of the target shaft and in-shaft pressure change data of the target shaft; according to the operation data, determining the risk level of abnormity of the target shaft; and according to the risk level, determining a sealed wellbore management and control strategy of the target wellbore. By the adoption of the technical scheme, the problem that the manual management and control efficiency of the sealed wellbore is low is solved.

Description

Technical Field

[0001] This application relates to the field of wellbore control, and more specifically, to a wellbore control strategy determination and device, storage medium, electronic device, and computer program product. Background Technology

[0002] In drilling and well workover operations, the complexity and uncertainty of the downhole environment pose significant challenges to operational safety and efficiency. Among these, lost circulation (VGF) and well control risks are two common problems, and their management and control are crucial for ensuring the smooth progress of operations. VGF occurs when drilling fluid or kill fluid seeps into the formation through formation fractures or pores during drilling. It not only increases operational costs but can also lead to well control accidents, severely impacting downhole safety. Therefore, monitoring the dynamics of downhole kill fluids, promptly detecting signs of VGF, and taking effective plugging measures are critical aspects of drilling operations.

[0003] Traditional well leakage monitoring methods primarily rely on surface monitoring equipment and personnel observation. Once leakage is detected, such as the return of pressureless well fluid from the guide channel outlet, it indicates a fluid leak downhole, requiring a rapid response to ensure well control safety. Simultaneously, well control risk management is another crucial aspect of drilling operations. Well control, or the control of well pressure, is a key measure to prevent blowouts and protect downhole equipment and personnel. During operations, if abnormal well pressure is detected or well control risks are anticipated, such as excessive formation pressure or drilling fluid loss, it may be necessary to urgently shut down the blowout preventer (BOP) to isolate downhole pressure and prevent blowouts. Well leakage monitoring and timely plugging, as well as BOP operation and fiber optic cable safety under well control risks, are important technical areas for ensuring smooth drilling operations and protecting downhole equipment and personnel. Traditional monitoring technologies, plugging measures, and BOP operation procedures suffer from problems such as untimely monitoring and ineffective plugging when dealing with complex downhole environments and emergencies, limiting the safety and efficiency of operations.

[0004] There is currently no effective solution to the problem of low efficiency in manual control of sealed wellbores in related technologies.

[0005] Therefore, it is necessary to improve the relevant technology to overcome the aforementioned defects. Summary of the Invention

[0006] This application provides a method for determining a wellbore control strategy, as well as a storage medium, electronic device, and computer program product, to at least address the problem of low efficiency in manual control of wellbores.

[0007] According to one aspect of the embodiments of this application, a method for determining a wellbore sealing and control strategy is provided, comprising: monitoring the operational data of a target wellbore, wherein the operational data includes at least: the return of kill fluid at the outlet of the guide channel of the target wellbore, and pressure change data inside the target wellbore; determining the risk level of an anomaly occurring in the target wellbore based on the operational data; and determining the wellbore sealing and control strategy for the target wellbore based on the risk level.

[0008] In an exemplary embodiment, determining the risk level of an anomaly in the target wellbore based on the operational data includes: obtaining a first configuration file, wherein the first configuration file contains well leakage levels corresponding to different flow rates and pressures; determining the target well leakage level based on the first configuration file, according to the target flow rate and target pressure, wherein the well kill fluid return status includes the target flow rate of the well kill fluid at the outlet of the guide channel, the target pressure is the pressure determined based on the pressure change data inside the wellbore, and the risk level includes the target well leakage level.

[0009] In an exemplary embodiment, determining the wellbore sealing and control strategy for the target wellbore based on the risk level includes: obtaining a second configuration file, wherein the second configuration file contains well leakage handling strategies corresponding to different well leakage levels; and determining a target well leakage handling strategy based on the second configuration file and the target well leakage level, wherein the risk level includes the target well leakage level, and the wellbore sealing and control strategy includes the target well leakage handling strategy.

[0010] In an exemplary embodiment, after determining the target well leakage treatment strategy based on the second configuration file according to the target well leakage level, the method further includes: adding the target dose of the target well leakage treatment strategy to the kill fluid at the inlet of the guide channel of the target wellbore when the target well leakage treatment strategy indicates the use of a target type of target plugging agent and the dose of the target plugging agent is a target dose.

[0011] In an exemplary embodiment, after adding the target dose of the target plugging agent to the kill fluid at the inlet of the guide channel of the target wellbore, the method further includes: real-time monitoring of the operating data of the target wellbore; and re-determining the target wellbore leakage treatment strategy based on the real-time monitored operating data, wherein the re-determined target wellbore leakage treatment strategy includes: adjusting the type and / or dose of the plugging agent added to the kill fluid at the inlet of the guide channel, and adjusting the temperature and / or density of the kill fluid in the target wellbore.

[0012] In an exemplary embodiment, determining the wellbore control strategy for the target wellbore based on the risk level includes: when the risk level indicates that the probability of a blowout in the target wellbore is greater than a preset probability, determining the wellbore control strategy as follows: cutting the downhole fiber optic cable passing through the blowout preventer in the target wellbore and shutting down the blowout preventer.

[0013] According to another aspect of the embodiments of this application, a device for determining a wellbore control strategy is also provided, comprising: a monitoring module for monitoring the operating data of a target wellbore, wherein the operating data includes at least: the return of kill fluid at the outlet of the guide channel of the target wellbore, and pressure change data inside the target wellbore; a first determining module for determining the risk level of an anomaly occurring in the target wellbore based on the operating data; and a second determining module for determining a wellbore control strategy for the target wellbore based on the risk level.

[0014] According to another aspect of the embodiments of this application, a computer-readable storage medium is also provided, the computer-readable storage medium including a stored program, wherein the program is configured to perform the determination of the above-mentioned wellbore control strategy at runtime.

[0015] According to another aspect of the embodiments of this application, an electronic device is also provided, including a memory and a processor, wherein the memory stores a computer program, and the processor is configured to perform the determination of the above-mentioned wellbore control strategy through the computer program.

[0016] According to another aspect of the embodiments of this application, a computer program product is also provided, including a computer program that, when executed by a processor, determines the above-mentioned wellbore control strategy.

[0017] This application monitors operational data such as the return of kill fluid from the outlet of the guide channel of the target wellbore and pressure changes within the wellbore. Based on this operational data, the risk level of anomalies in the target wellbore is determined, thereby determining the wellbore control strategy. This avoids manual control of the wellbore, improves the efficiency of wellbore control, and solves the problem of low efficiency in manual wellbore control. Attached Figure Description

[0018] The accompanying drawings, which are incorporated in and form part of this specification, illustrate embodiments consistent with this application and, together with the description, serve to explain the principles of this application.

[0019] To more clearly illustrate the technical solutions in the embodiments of this application or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, for those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0020] Figure 1 This is a hardware structure block diagram of a mobile terminal for determining a wellbore control strategy according to an embodiment of this application.

[0021] Figure 2 This is a flowchart illustrating the determination of a wellbore control strategy according to an embodiment of this application;

[0022] Figure 3 This is a structural block diagram of a device for determining a wellbore control strategy according to an embodiment of this application. Detailed Implementation

[0023] To enable those skilled in the art to better understand the present application, the technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present application, and not all embodiments. Based on the embodiments in the present application, all other embodiments obtained by those of ordinary skill in the art without creative effort should fall within the scope of protection of the present application.

[0024] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings of this application are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of this application described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0025] The methods and embodiments provided in this application can be executed on a mobile terminal, computer terminal, or similar computing device. Taking running on a mobile terminal as an example, Figure 1 This is a hardware structure block diagram of a mobile terminal used to determine a wellbore control strategy according to an embodiment of this application. Figure 1 As shown, a mobile terminal may include one or more ( Figure 1Only one is shown in the diagram. A processor 102 (which may include, but is not limited to, a microprocessor (MP) or a field-programmable gate array (FPGA)) and a memory 104 for storing data are also shown. The mobile terminal may further include a transmission device 106 for communication functions and an input / output device 108. Those skilled in the art will understand that... Figure 1 The structure shown is for illustrative purposes only and does not limit the structure of the mobile terminal described above. For example, the mobile terminal may also include components that are more... Figure 1 The more or fewer components shown, or having the same Figure 1 The different configurations shown.

[0026] The memory 104 can be used to store computer programs, such as application software programs and modules, like the computer program corresponding to the determination of the wellbore control strategy in this embodiment. The processor 102 executes various functional applications and data processing by running the computer programs stored in the memory 104, thus implementing the above-described method. The memory 104 may include high-speed random access memory and non-volatile memory, such as one or more magnetic storage devices, flash memory, or other non-volatile solid-state memory. In some instances, the memory 104 may further include memory remotely located relative to the processor 102, and these remote memories can be connected to a mobile terminal via a network. Examples of such networks include, but are not limited to, the Internet, corporate intranets, local area networks, mobile communication networks, and combinations thereof.

[0027] The transmission device 106 is used to receive or send data via a network. Specific examples of the network described above may include a wireless network provided by the mobile terminal's communication provider. In one example, the transmission device 106 includes a Network Interface Controller (NIC), which can connect to other network devices via a base station to communicate with the Internet. In another example, the transmission device 106 may be a Radio Frequency (RF) module used for wireless communication with the Internet.

[0028] To address the aforementioned issues, this embodiment provides a method for determining a wellbore control strategy, including but not limited to applications in the aforementioned mobile terminal. Figure 2 This is a flowchart illustrating the determination of a wellbore control strategy according to an embodiment of this application, such as... Figure 2 As shown, the process includes the following steps S202-S206:

[0029] Step S202: Monitor the operating data of the target wellbore, wherein the operating data includes at least: the return of kill fluid at the outlet of the guide channel of the target wellbore, and the pressure change data inside the target wellbore;

[0030] Optionally, a precise real-time monitoring and early warning system can be established during drilling operations. This system needs to continuously monitor the pressure and flow rate of downhole fluids, as well as the return of kill fluid from the guide channel outlet. By installing high-precision sensors and data acquisition devices, downhole data is collected in real time, and advanced data analysis technology is used to process and recognize patterns in real time to detect downhole anomalies, such as lost circulation, as early as possible.

[0031] Optionally, during this stage, the monitoring system continuously collects operational data of the target wellbore, including but not limited to the return of kill fluid at the outlet of the guide channel and pressure change data within the wellbore.

[0032] It should be noted that monitoring the return of kill fluid can promptly detect signs of well leakage, while data on changes in drilling fluid pressure within the wellbore helps assess well control risks, including abnormal increases in formation pressure or unplanned losses of drilling fluid. High-precision sensors and data acquisition equipment ensure the accuracy and real-time nature of the data, providing a solid foundation for subsequent risk assessments.

[0033] Step S204: Determine the risk level of the target wellbore anomaly based on the operational data;

[0034] Optionally, based on the collected operational data, advanced data analysis algorithms and pattern recognition technologies are used to comprehensively assess the downhole conditions and determine the risk level of well leakage or well control anomalies in the target wellbore. The risk level can be multi-tiered, from low to high, with each level corresponding to a different response plan. For example, low risk may only require close monitoring, while high risk may require immediate emergency measures, such as adding plugging agents or shutting down the blowout preventer. This tiered response mechanism ensures that the most appropriate measures are taken in different risk scenarios, avoiding overreaction that increases operational costs while ensuring rapid response in high-risk situations to protect downhole equipment and personnel safety.

[0035] Step S206: Determine the wellbore sealing and control strategy for the target wellbore based on the risk level.

[0036] Optionally, once the risk level is determined, the next step is to determine the specific wellbore control strategy based on that level. For example, at low risk: continue monitoring and maintain close attention to the downhole conditions to ensure timely response if the risk escalates; at medium risk: activate the early warning mechanism, notify operators to be vigilant, and prepare emergency supplies and equipment, such as plugging agents and pipe cutters; at high risk: immediately implement emergency measures, such as adding plugging agents to the kill fluid in the event of well leakage and circulating the kill fluid to seal the leak; under well control risk, it is necessary to use a pipe cutter to quickly cut the downhole armored fiber optic cable passing through the blowout preventer, and then shut down the blowout preventer to isolate downhole pressure and prevent a blowout accident.

[0037] It should be noted that implementing the above steps can effectively reduce uncertainties and risks in downhole operations, and improve the accuracy and efficiency of well control management. Real-time monitoring systems and intelligent analysis can promptly detect downhole anomalies, ensuring the timely execution of emergency measures. Through tiered response and the implementation of specific strategies, well leakage and well control risks can be effectively controlled and reduced, decreasing the probability of downhole accidents. Intelligent management strategies can select the most appropriate response measures based on the actual situation, avoiding unnecessary resource waste and effectively controlling operating costs. Protective measures for the downhole armored fiber optic cable ensure that the downhole communication system can maintain a certain level of operation in emergency situations, improving the overall safety of operations.

[0038] The above steps monitor operational data such as the return of kill fluid from the outlet of the target wellbore's guide channel and pressure changes within the wellbore. Based on this operational data, the risk level of any anomaly in the target wellbore is determined, thereby establishing a wellbore control strategy. This avoids the need for manual control of the wellbore, improves the efficiency of wellbore control, and ultimately solves the problem of low efficiency in manual wellbore control.

[0039] In an exemplary embodiment, determining the risk level of an anomaly in the target wellbore based on the operational data can be achieved through the following steps S11-S12:

[0040] Step S11: Obtain the first configuration file, wherein the first configuration file contains well leakage levels corresponding to different flow rates and pressures;

[0041] Optionally, the first configuration file is developed based on extensive experimental data, historical case analysis, and formation characteristic studies. It uses the flow rate of the kill fluid and pressure changes within the wellbore as key parameters. By combining these parameters, the well control status can be quickly assessed, and the risk level of well leakage can be predicted. For example, the configuration file can specify that the wellbore is at a high risk level under low flow rate and high pressure conditions, while it is at a low risk level under normal flow rate and normal pressure conditions. This parameter-based classification allows the system to make more accurate judgments about downhole conditions.

[0042] Step S12: Based on the first configuration file, determine the target well leakage level according to the target flow rate and target pressure, wherein the well kill fluid return status includes the target flow rate of the well kill fluid at the outlet of the guide channel, the target pressure is the pressure determined according to the pressure change data inside the cylinder, and the risk level includes the target well leakage level.

[0043] Optionally, the system will match the target flow rate and target pressure data of the kill fluid returned in real time with the parameters in the first configuration file to automatically determine the current wellbore leakage risk level. For example, if a significant decrease in the kill fluid flow rate at the guide channel outlet is detected, and an abnormal increase in pressure occurs in the wellbore, the system will map these parameters to a predefined high-risk level according to the rules in the configuration file. Once the risk level is determined, corresponding emergency strategies can be immediately activated, such as taking plugging measures or preparing to shut down the blowout preventer, to address potential well control risks.

[0044] It should be noted that by matching flow and pressure data with rules in the configuration file, the system can quickly and accurately assess the risk level of well leakage, avoiding the subjectivity and delays of manual judgment and improving the scientific rigor and real-time nature of the assessment. Based on real-time monitoring of target flow and target pressure, the system can automatically trigger early warnings and, according to the risk level in the configuration file, promptly notify operators and the control system to take countermeasures, thereby enhancing operational safety.

[0045] In an exemplary embodiment, determining the wellbore sealing and control strategy based on the risk level can be achieved through the following steps S21-S22:

[0046] Step S21: Obtain the second configuration file, wherein the second configuration file contains well leakage handling strategies corresponding to different well leakage levels;

[0047] Optionally, the system will further obtain a second profile based on the previously determined target well leakage level. This profile contains treatment strategies for different well leakage levels. For example, for low-level well leakage, it may only be necessary to increase the density of the kill fluid and monitor whether the leakage situation improves; while for high-level well leakage, it may be necessary to immediately add a specific plugging agent and prepare to shut down the blowout preventer to prevent further well control risks. Obtaining the second profile ensures that the system can select the most appropriate treatment method according to the severity of the well leakage, avoiding excessive or insufficient intervention and improving the safety and economy of the operation.

[0048] Step S22: Based on the second configuration file, determine the target well leakage treatment strategy according to the target well leakage level, wherein the risk level includes the target well leakage level, and the wellbore sealing and control strategy includes the target well leakage treatment strategy.

[0049] Optionally, after determining the target well leakage level, the system will automatically determine and execute the target well leakage treatment strategy by referring to the corresponding strategy in the second configuration file. For example, if the system assesses the current wellbore leakage level as high, according to the second configuration file, it will immediately initiate the following strategy: select and add a high-efficiency plugging agent, and seal the leak by circulating kill fluid; simultaneously, if the well control risk further aggravates, the system will cut the armored fiber optic cable and then shut down the blowout preventer to ensure the safety of downhole equipment and personnel. The entire process is controlled by an automated system, ensuring the timeliness and accuracy of strategy execution.

[0050] It should be noted that the second configuration file can provide optimized handling strategies for different levels of well leakage. This mechanism ensures that operators can take the most suitable emergency measures when facing different risks, improving leakage plugging efficiency while avoiding unnecessary operations and reducing operating costs. Based on intelligent judgment of the target well leakage level and automated strategy execution, the system can respond instantly to changes in downhole conditions, reducing delays and uncertainties caused by manual decision-making and enhancing the safety and reliability of operations.

[0051] In an exemplary embodiment, after determining the target well leakage treatment strategy based on the second configuration file according to the target well leakage level, the method further includes the following step: when the target well leakage treatment strategy indicates the use of a target type of target plugging agent and the dosage of the target plugging agent is a target dosage, adding the target dosage of the target plugging agent to the kill fluid at the inlet of the guide channel of the target wellbore.

[0052] Optionally, after determining the target wellbore leakage treatment strategy according to the second configuration file, if the strategy indicates the use of a specific type of target plugging agent and specifies the dosage of the plugging agent, the system will add the target dosage of the target plugging agent to the kill fluid at the inlet of the guide channel of the target wellbore. This step is the actual operation in the leakage plugging process, aiming to effectively seal downhole leakage points by adding a specific type and dosage of plugging agent to the kill fluid. This step includes: plugging agent preparation and addition: the system prepares the target type of plugging agent according to the target wellbore leakage treatment strategy and ensures that the addition amount meets the target dosage requirements. The selection of the plugging agent is based on the nature and degree of wellbore leakage and formation characteristics to ensure that it can effectively form a physical or chemical barrier to seal the leakage point; kill fluid circulation: the kill fluid with the target plugging agent added is sent downhole through the circulation system to ensure that the plugging agent can be evenly distributed and reach the downhole leakage point. During the circulation process, the system continuously monitors the flow of the kill fluid and changes in downhole pressure to assess the distribution effect of the plugging agent and the progress of leak sealing. Leak sealing effect monitoring: While the kill fluid is circulating, the return of the kill fluid from the guide channel outlet and the downhole pressure are closely monitored. By comparing data before and after plugging, the plugging effect is evaluated to confirm whether the leak has been effectively sealed.

[0053] It should be noted that, through the above steps, guided by the target well leakage level and the second configuration file, the embodiments of this application can accurately select the most suitable type and dosage of plugging agent, achieve precise plugging, effectively avoid further loss of downhole fluid, implement a precise plugging strategy, effectively seal downhole leaks, reduce well control risks such as well blowouts, and ensure the safety of downhole equipment and personnel.

[0054] In an exemplary embodiment, after adding the target dose of the target plugging agent to the kill fluid at the inlet of the guide channel of the target wellbore, the method further includes the following steps S31-S32:

[0055] Step S31: Monitor the operating data of the target wellbore in real time;

[0056] Optionally, during the process of adding the lost circulation agent to the kill fluid and beginning its circulation downhole, the system continuously performs real-time monitoring, collecting operational data from the target wellbore. This data includes, but is not limited to, key indicators such as kill fluid return, downhole pressure changes, and the temperature and density of the kill fluid. The purpose of real-time monitoring is to assess the sealing effect of the lost circulation agent while simultaneously monitoring changes in the downhole environment to ensure operational safety and well control stability.

[0057] Step S32: Determine the target well leakage treatment strategy again based on the real-time monitored operating data. The re-determined target well leakage treatment strategy includes: adjusting the type and / or dosage of the plugging agent added to the kill fluid at the inlet of the guide channel, and adjusting the temperature and / or density of the kill fluid in the target wellbore.

[0058] Optionally, if the currently used plugging agent is ineffective, the system may switch to a more efficient type of plugging agent or increase the dosage of the plugging agent to enhance its sealing ability. To improve the performance of the plugging agent or adapt to changes in the downhole environment, the system may need to adjust the temperature or density of the kill fluid. For example, increasing the density of the kill fluid helps increase the sealing pressure, while changing the temperature may affect the chemical reaction rate of the plugging agent, thereby optimizing the sealing effect.

[0059] It should be noted that the real-time monitoring and strategy adjustment mechanism ensures that the system can dynamically adjust the well leakage treatment strategy according to changes in the downhole environment, improving plugging efficiency and operational safety. Compared with static strategies, dynamic adjustment can more flexibly cope with complex and ever-changing downhole conditions. Through continuous monitoring, the system can promptly detect deficiencies in the plugging effect, thereby making targeted strategy adjustments to maximize the plugging effect and reduce the impact and cost of well leakage on operations. Real-time monitoring not only evaluates the effectiveness of the current strategy but also provides early warnings of potential risks, such as abnormal increases in downhole pressure, allowing the system to react in advance and take preventative control measures to avoid well control accidents.

[0060] It should be noted that through steps S31-S32, continuous optimization and dynamic response to well leakage management in downhole operations can be achieved, significantly improving the safety level, efficiency and resource management capabilities of downhole operations, and providing an innovative technical solution for risk control under complex downhole conditions.

[0061] In an exemplary embodiment, determining the wellbore sealing and control strategy for the target wellbore based on the risk level can be achieved through the following steps: when the risk level indicates that the probability of a blowout in the target wellbore is greater than a preset probability, the wellbore sealing and control strategy is determined to be: cutting the downhole fiber optic cable passing through the blowout preventer of the target wellbore and shutting down the blowout preventer.

[0062] It should be noted that a specialized pipe cutter is used to cut the downhole fiber optic cable passing through the blowout preventer (BOP) in the target wellbore. This operation aims to prevent damage to the cable when the BOP is closed, and also to prevent it from becoming an additional safety hazard in the event of a blowout. Ensuring the efficiency and accuracy of the fiber optic cable cutting is a crucial step in protecting the downhole communication system and the safety of personnel.

[0063] It should be noted that once the downhole fiber optic cable is safely severed, the next step is to immediately shut down the blowout preventer (BOP) to seal the annulus. The emergency shutdown of the BOP can quickly isolate the high-pressure downhole environment and prevent uncontrolled leakage of fluids from the well, i.e., a blowout. This measure is currently the most direct and effective means of dealing with the high probability of a blowout under existing technological conditions.

[0064] It should be noted that, under the high probability of blowout risk, quickly cutting off the optical cable and shutting down the blowout preventer effectively avoids blowout accidents, greatly improves the safety level of downhole operations, and enhances the efficiency of emergency response.

[0065] Obviously, the embodiments described above are merely some embodiments of the present invention, and not all embodiments. To better understand the above method, the following description, in conjunction with embodiments, illustrates the process, but is not intended to limit the technical solutions of the embodiments of the present invention. Specifically:

[0066] I. Establishment of a real-time monitoring and early warning system:

[0067] During drilling operations, a precise real-time monitoring and early warning system must be established. This system needs to continuously monitor the pressure and flow rate of downhole fluids, as well as the return of kill fluid from the guide channel outlet. By installing high-precision sensors and data acquisition devices, downhole data is collected in real time, and advanced data analysis technology is used to process and identify patterns in real time to detect downhole anomalies, such as lost circulation, as early as possible.

[0068] II. Well Leakage Identification and Response:

[0069] (1) Identification stage:

[0070] The monitoring system continuously monitors the return of kill fluid at the outlet of the guide channel. If no kill fluid is detected returning from the outlet, this usually indicates a possible fluid leak downhole, i.e., lost circulation. In this case, further analysis of parameters such as pressure changes and flow loss is conducted to confirm the exact nature of the lost circulation, including the location, amount, and rate of leakage.

[0071] (2) Response phase:

[0072] Once a well leakage is confirmed, the emergency plan should be activated immediately, and leakage plugging measures should be taken. First, an appropriate amount of plugging agent should be added to the kill fluid. The choice of plugging agent depends on the nature and extent of the leakage, as well as the characteristics of the formation. The plugging agent can be granular, fibrous, or chemical; it forms a physical or chemical barrier in the kill fluid to seal the leakage point.

[0073] (3) Implementation steps:

[0074] 1. Preparation of plugging agent: Based on the monitored well leakage, quickly determine the type and amount of plugging agent to be added;

[0075] 2. Kill fluid circulation: The kill fluid with added plugging agent is circulated to the downhole through the drilling fluid circulation system to ensure that the plugging agent can be evenly distributed and reach the leakage point;

[0076] 3. Leakage monitoring: While the plugging agent is circulating, continuously monitor the downhole pressure and the return flow at the guide channel outlet to evaluate the plugging effect;

[0077] 4. Adjust strategy: If the initial plugging effect is not good, the type and amount of plugging agent need to be adjusted, or other auxiliary plugging measures should be taken, such as changing the density or temperature of the drilling fluid, to optimize the plugging effect.

[0078] 5. Confirmation of sealing: Once the return of the kill fluid is monitored and the pressure is stable, it can be confirmed that the leak has been effectively sealed. At this time, normal drilling operations can be gradually resumed, while monitoring continues to prevent the well leakage from recurring.

[0079] III. Blowout Preventer Operation and Fiber Optic Cable Protection under Well Control Risks:

[0080] In drilling operations, well control risks can arise from various causes, such as abnormal formation pressure, drilling fluid loss, or downhole equipment malfunction. When the monitoring system issues a well control risk warning and requires emergency shutdown of the blowout preventer (BOP), special protective measures must be taken to prevent damage to the downhole armored fiber optic cable during BOP shutdown, which could affect the normal operation of the downhole communication system, given the presence of the cable. First, a specialized pipe cutter is used to cut the downhole armored fiber optic cable passing through the BOP. The pipe cutter must have high precision and rapid cutting capabilities to ensure efficient and accurate cable cutting while avoiding unnecessary damage to the cable or surrounding equipment. After cutting the cable, the BOP is immediately used to seal the annulus to isolate downhole pressure and prevent a blowout.

[0081] Through the above description of the embodiments, those skilled in the art can clearly understand that the methods according to the above embodiments can be implemented by means of software plus necessary general-purpose hardware platforms. Of course, they can also be implemented by hardware, but in many cases the former is a better implementation method. Based on this understanding, the technical solution of this application, in essence, or the part that contributes to the prior art, can be embodied in the form of a software product. This computer software product is stored in a storage medium (such as ROM / RAM, magnetic disk, optical disk) and includes several instructions to cause a terminal device (which may be a mobile phone, computer, server, or network device, etc.) to execute the methods of the various embodiments of this application.

[0082] This embodiment also provides a device for determining a wellbore control strategy. This device is used to implement the above embodiments and preferred embodiments, and details already described will not be repeated. As used below, the term "module" can be a combination of software and / or hardware that performs a predetermined function. Although the device described in the following embodiments is preferably implemented in software, hardware implementation, or a combination of software and hardware, is also possible and contemplated.

[0083] Figure 3 This is a structural block diagram of a device for determining a wellbore control strategy according to an embodiment of this application. The device includes:

[0084] The monitoring module 302 is used to monitor the operating data of the target wellbore, wherein the operating data includes at least: the return of kill fluid at the outlet of the guide channel of the target wellbore, and the pressure change data inside the target wellbore;

[0085] The first determining module 304 is used to determine the risk level of an anomaly occurring in the target wellbore based on the operational data;

[0086] The second determining module 306 is used to determine the sealing and control strategy of the target wellbore based on the risk level.

[0087] The aforementioned device monitors operational data such as the return of kill fluid from the outlet of the guide channel of the target wellbore and pressure changes within the wellbore. Based on this operational data, it determines the risk level of any abnormality in the target wellbore and thus determines the wellbore control strategy. This avoids the need for manual control of the wellbore, improves the efficiency of wellbore control, and solves the problem of low efficiency in manual wellbore control.

[0088] In an exemplary embodiment, the first determining module 304 is further configured to obtain a first configuration file, wherein the first configuration file contains well leakage levels corresponding to different flow rates and pressures; based on the first configuration file, a target well leakage level is determined according to a target flow rate and a target pressure, wherein the well kill fluid return status includes the target flow rate of the well kill fluid at the outlet of the guide channel, the target pressure is the pressure determined according to the pressure change data inside the cylinder, and the risk level includes the target well leakage level.

[0089] In an exemplary embodiment, the second determining module 306 is further configured to obtain a second configuration file, wherein the second configuration file contains well leakage handling strategies corresponding to different well leakage levels; based on the second configuration file, a target well leakage handling strategy is determined according to the target well leakage level, wherein the risk level includes the target well leakage level, and the wellbore sealing and control strategy includes the target well leakage handling strategy.

[0090] In an exemplary embodiment, the above-described apparatus further includes: a processing module, configured to, after determining a target well leakage treatment strategy based on the second configuration file and according to the target well leakage level, add the target dose of the target plugging agent to the kill fluid at the inlet of the guide channel of the target wellbore, provided that the target well leakage treatment strategy indicates the use of a target type of target plugging agent and the dose of the target plugging agent is a target dose.

[0091] In an exemplary embodiment, the second determining module 306 is further configured to monitor the operating data of the target wellbore in real time after adding the target dose of the target plugging agent to the kill fluid at the inlet of the guide channel of the target wellbore; and to determine the target wellbore leakage treatment strategy again based on the real-time monitored operating data, wherein the re-determined target wellbore leakage treatment strategy includes: adjusting the type and / or dose of the plugging agent added to the kill fluid at the inlet of the guide channel, and adjusting the temperature and / or density of the kill fluid in the target wellbore.

[0092] In an exemplary embodiment, the second determining module 306 is further configured to determine the wellbore control strategy as follows: cutting the downhole optical cable of the blowout preventer passing through the target wellbore and shutting down the blowout preventer when the risk level indicates that the probability of a blowout in the target wellbore is greater than a preset probability.

[0093] Embodiments of this application also provide a computer-readable storage medium storing a computer program, wherein the computer program is configured to execute the steps in any of the above method embodiments when run.

[0094] Optionally, in this embodiment, the storage medium may be configured to store a computer program for performing the following steps:

[0095] S1, monitor the operating data of the target wellbore, wherein the operating data includes at least: the return of kill fluid at the outlet of the guide channel of the target wellbore, and the pressure change data inside the target wellbore;

[0096] S2, determine the risk level of an anomaly occurring in the target wellbore based on the operational data;

[0097] S3, determine the wellbore sealing and control strategy for the target wellbore based on the risk level.

[0098] In one exemplary embodiment, the aforementioned computer-readable storage medium may include, but is not limited to, various media capable of storing computer programs, such as a USB flash drive, read-only memory (ROM), random access memory (RAM), portable hard disk, magnetic disk, or optical disk.

[0099] Specific examples in this embodiment can be found in the examples described in the above embodiments and exemplary implementations, and will not be repeated here.

[0100] Embodiments of this application also provide a computer program product, including a computer program, wherein the computer program, when executed by a processor, performs the steps in any of the above method embodiments.

[0101] Embodiments of this application also provide an electronic device including a memory and a processor, wherein the memory stores a computer program and the processor is configured to run the computer program to perform the steps in any of the above method embodiments.

[0102] Optionally, in this embodiment, the processor can be configured to perform the following steps via a computer program:

[0103] S1, monitor the operating data of the target wellbore, wherein the operating data includes at least: the return of kill fluid at the outlet of the guide channel of the target wellbore, and the pressure change data inside the target wellbore;

[0104] S2, determine the risk level of an anomaly occurring in the target wellbore based on the operational data;

[0105] S3, determine the wellbore sealing and control strategy for the target wellbore based on the risk level.

[0106] In one exemplary embodiment, the electronic device may further include a transmission device and an input / output device, wherein the transmission device is connected to the processor and the input / output device is connected to the processor.

[0107] Specific examples in this embodiment can be found in the examples described in the above embodiments and exemplary implementations, and will not be repeated here.

[0108] Obviously, those skilled in the art should understand that the modules or steps of this application described above can be implemented using general-purpose computing devices. They can be centralized on a single computing device or distributed across a network of multiple computing devices. They can be implemented using computer-executable program code, and thus can be stored in a storage device for execution by a computing device. In some cases, the steps shown or described can be performed in a different order than those presented here, or they can be fabricated as separate integrated circuit modules, or multiple modules or steps can be fabricated as a single integrated circuit module. Thus, this application is not limited to any particular combination of hardware and software.

[0109] The above description is only a preferred embodiment of this application. It should be noted that for those skilled in the art, several improvements and modifications can be made without departing from the principle of this application, and these improvements and modifications should also be considered within the scope of protection of this application.

Claims

1. A method for determining a wellbore control strategy, characterized in that, include: The operation data of the target wellbore is monitored, wherein the operation data includes at least: the return of kill fluid at the outlet of the guide channel of the target wellbore, and the pressure change data inside the target wellbore; The risk level of an anomaly in the target wellbore is determined based on the operational data. The sealing and control strategy for the target wellbore is determined based on the risk level.

2. The method according to claim 1, characterized in that, Determining the risk level of an anomaly in the target wellbore based on the operational data includes: Obtain a first configuration file, wherein the first configuration file contains well leakage levels corresponding to different flow rates and pressures; Based on the first configuration file, the target well leakage level is determined according to the target flow rate and the target pressure, wherein the well kill fluid return status includes the target flow rate of the well kill fluid at the outlet of the guide channel, the target pressure is the pressure determined based on the pressure change data inside the cylinder, and the risk level includes the target well leakage level.

3. The method according to claim 1, characterized in that, Based on the risk level, a wellbore sealing and management strategy is determined, including: Obtain a second configuration file, wherein the second configuration file contains well leakage handling strategies corresponding to different well leakage levels; Based on the second configuration file, a target well leakage treatment strategy is determined according to the target well leakage level, wherein the risk level includes the target well leakage level, and the wellbore sealing and control strategy includes the target well leakage treatment strategy.

4. The method according to claim 3, characterized in that, Based on the second configuration file, after determining the target well leakage treatment strategy according to the target well leakage level, the method further includes: When the target well leakage treatment strategy indicates the use of a target type of target plugging agent and the dosage of the target plugging agent is a target dosage, the target dosage of the target plugging agent is added to the kill fluid at the inlet of the guide channel of the target wellbore.

5. The method according to claim 4, characterized in that, After adding the target dose of the target plugging agent to the kill fluid at the inlet of the guide channel of the target wellbore, the method further includes: Real-time monitoring of the target wellbore's operational data; Based on the real-time monitored operating data, the target well leakage treatment strategy is determined again. The determined target well leakage treatment strategy includes: adjusting the type and / or dosage of the plugging agent added to the kill fluid at the inlet of the guide channel, and adjusting the temperature and / or density of the kill fluid in the target wellbore.

6. The method according to claim 1, characterized in that, Based on the risk level, a wellbore sealing and management strategy is determined, including: If the risk level indicates that the probability of a blowout in the target wellbore is greater than a preset probability, the wellbore control strategy is determined to be: cut the downhole fiber optic cable passing through the blowout preventer in the target wellbore and shut down the blowout preventer.

7. A device for determining a wellbore control strategy, characterized in that, include: The monitoring module is used to monitor the operating data of the target wellbore, wherein the operating data includes at least: the return of kill fluid at the outlet of the guide channel of the target wellbore, and the pressure change data inside the target wellbore; The first determining module is used to determine the risk level of an anomaly occurring in the target wellbore based on the operational data; The second determining module is used to determine the sealing and control strategy for the target wellbore based on the risk level.

8. A computer-readable storage medium, characterized in that, The computer-readable storage medium includes a stored program, wherein the program, when executed, performs the method of any one of claims 1 to 6.

9. An electronic device comprising a memory and a processor, characterized in that, The memory stores a computer program, and the processor is configured to execute the method of any one of claims 1 to 6 through the computer program.

10. A computer program product, comprising a computer program, characterized in that, When the computer program is executed by a processor, it implements the method of any one of claims 1 to 6.

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