Shaft integrity evaluation method and system, processing equipment and storage medium

Abstract

The invention relates to a wellbore integrity assessment method and system, processing equipment and a storage medium, and is characterized in that the method comprises the steps: employing a Duwaval triangle method, detecting the chemical component change of a fluid in a to-be-assessed wellbore, determining the risk degree of the fluid in the to-be-assessed wellbore, and determining the analysis conditions under different risk levels; comprehensively analyzing the chemical component change of the fluid in the to-be-assessed shaft, the risk degree of the fluid in the to-be-assessed shaft and the data of the to-be-assessed shaft obtained in real time by adopting an inductive decision tree model to obtain the current integrity state of the to-be-assessed shaft, and if potential risks exist in the to-be-assessed shaft, performing early warning. The method can provide more comprehensive shaft integrity information, and can be widely applied to the field of shaft integrity monitoring.

Description

Technical Field

[0001] The present invention relates to the field of wellbore integrity monitoring, and in particular to a wellbore integrity assessment method, system, processing equipment and storage medium. Background Art

[0002] In the oil extraction industry, accurate monitoring of wellbore integrity is of vital importance. Traditional wellbore integrity monitoring methods have significant limitations in the following aspects: insufficient detection sensitivity. Traditional methods usually rely on physical detection tools or visual inspections, which are limited in their effectiveness in identifying small cracks or corrosion problems in the wellbore at an early stage; limited data analysis capabilities. When processing and analyzing complex data collected from the wellbore, traditional methods may not be able to effectively identify complex failure modes, resulting in insufficient accuracy and timeliness of diagnosis; lack of comprehensive risk assessment, focusing mainly on detecting existing damage rather than evaluating and predicting potential future risks, which limits the foresight of wellbore management.

[0003] At present, the existing technology discloses some wellbore integrity assessment methods, including: 1) Using conventional chemical analysis methods to detect oil and gas wells, by regularly sampling the fluid in the wellbore, and then performing chemical analysis on the samples in the laboratory to determine the chemical composition and properties of the fluid in the wellbore. 2) Using physical sensors to monitor wellbore integrity, using various physical sensors (such as pressure and temperature sensors) to monitor the wellbore environment. 3) Using sound or ultrasonic methods to detect the structural integrity of the wellbore. 4) Using high-resolution cameras and image recognition technology to visually inspect the inner wall of the wellbore. 5) Using historical data collected from the wellbore (such as pressure, temperature and chemical analysis results) to build a predictive maintenance model. 6) Using physical models, combined with the design parameters and operating data of the wellbore, to evaluate the integrity of the wellbore.

[0004] However, existing wellbore integrity assessment methods face multiple challenges, the core problem is that they cannot provide real-time, comprehensive and accurate wellbore status monitoring. First, conventional chemical analysis methods rely on offline sampling and laboratory testing. Although this method can provide some chemical information, it may miss early minor damage or changes in the wellbore due to the inability to monitor in real time. Second, although physical sensors such as pressure and temperature sensors can provide real-time data, they often cannot be directly associated with specific problems of wellbore structural integrity, and their long-term stability and accuracy in the harsh downhole environment may be affected. In addition, although acoustic and ultrasonic methods can detect cracks and corrosion in the wellbore wall, their detection accuracy is limited in complex downhole environments, multiphase flow and high noise conditions. At the same time, high-resolution cameras and image recognition methods may not provide high-quality images in multiphase flow or harsh environments, thus limiting their application in wellbore integrity monitoring. Finally, although predictive maintenance models based on historical data can predict potential problems, these models may have limitations in interpreting data and providing specific structural integrity information. In summary, existing technologies have obvious shortcomings in providing real-time, accurate and comprehensive wellbore integrity assessments. Summary of the invention

[0005] In view of the above problems, an object of the present invention is to provide a wellbore integrity assessment method, system, processing equipment and storage medium that can provide real-time, accurate and comprehensive wellbore integrity assessment.

[0006] To achieve the above objectives, the present invention adopts the following technical solutions: In a first aspect, a wellbore integrity assessment method is provided, which is characterized by comprising: The Duval triangle method is used to detect the changes in the chemical composition of the fluid in the wellbore to be evaluated, determine the risk level of the fluid in the wellbore to be evaluated, and determine the analysis conditions under different risk levels; An inductive decision tree model is used to comprehensively analyze the changes in the chemical composition of the fluid in the wellbore to be evaluated, the risk level of the fluid in the wellbore to be evaluated, and the real-time data of the wellbore to be evaluated to obtain the current integrity status of the wellbore to be evaluated. If there is a potential risk in the wellbore to be evaluated, an early warning will be issued.

[0007] Furthermore, the Duval triangle method is used to detect the chemical composition changes of the fluid in the wellbore to be evaluated, determine the risk level of the fluid in the wellbore to be evaluated, and determine the analysis conditions under different risk levels, including: 1.1) Use the Duval triangle method to detect the chemical composition changes of the fluid in the wellbore to be evaluated; 1.2) According to the chemical composition changes of the fluid in the wellbore to be evaluated and the pre-set cement sheath risk range, determine the risk level of the fluid in the wellbore to be evaluated, including high risk, medium risk, low risk or normal. If the risk level of the fluid in the wellbore to be evaluated is high risk, proceed to 1.3); if the risk level of the fluid in the wellbore to be evaluated is medium risk, proceed to 1.4); if the risk level of the fluid in the wellbore to be evaluated is low risk or normal, proceed to 1.5); 1.3) Determine different analysis situations under high risk level according to the relative pressure change of the AB annulus of the wellbore to be evaluated and the preset relative value of change; 1.4) Determine different analysis situations under medium risk level according to the relative pressure change of the AB annulus of the wellbore to be evaluated and the preset relative value of change; 1.5) Based on the CBL logging data of the wellbore to be evaluated, determine different analysis situations under low risk or normal level.

[0008] Furthermore, the different analysis situations under high risk levels are determined according to the relative pressure change of the AB annulus of the wellbore to be evaluated and the preset relative value of the change, including: 1.3.1) Determine the relative pressure change of the AB annulus of the wellbore to be evaluated. If the determined relative pressure change of the AB annulus is lower than the preset relative value, proceed to 1.3.2); otherwise, obtain the first analysis situation; 1.3.2) Measure the wellbore temperature of the wellbore to be evaluated. If the measured wellbore temperature exceeds a preset temperature critical value, a second analysis situation is obtained; otherwise, a third analysis situation is obtained.

[0009] Furthermore, the different analysis situations under the medium risk level are determined according to the relative pressure change of the AB annulus of the wellbore to be evaluated and the preset relative value of the change, including: 1.4.1) Determine the relative pressure change of the AB annulus of the wellbore to be evaluated. If the determined relative pressure change of the AB annulus is higher than the preset relative value, proceed to 1.3.2); otherwise, proceed to 1.4.2); 1.4.2) Measure the oil and gas production of the wellbore to be evaluated. If the measured oil and gas production exceeds a preset oil and gas production critical value, a fourth analysis situation is obtained; otherwise, a fifth analysis situation is obtained.

[0010] Furthermore, the determination of different analysis situations at low risk or normal levels based on the CBL logging data of the wellbore to be evaluated includes: 1.5.1) Analyze CBL logging data for the wellbore to be evaluated; 1.5.2) Based on the CBL logging data analysis results, re-evaluate the cement sheath quality. If the cement sheath quality is defective, proceed to 1.4.1); if the cement sheath quality is normal, proceed to 1.5.3); 1.5.3) Perform a simple assessment of the oil and gas production quality of the wellbore to be assessed. If the oil and gas quality is abnormal, proceed to 1.4.2); if the oil and gas quality is normal, the analysis of the wellbore to be assessed is normal.

[0011] Furthermore, the condition of the first analysis situation is that there is a preset positive correlation between annulus A and annulus B, and the pressure of annulus A and the pressure of annulus B are both higher than the average value, indicating that the isolation valve of the wellbore to be evaluated may fail or the casing may leak. In this analysis situation, it is necessary to further check the pressure changes of annulus A and annulus B, and whether the wellbore temperature exceeds the normal range; The condition of the second analysis situation is that the pressure of the B annulus is greater than a preset value, indicating that the cementing quality is poor or the casing is leaking; in this analysis situation, it is necessary to further check the pressure change of the B annulus and the overall condition of the wellbore; The condition of the third analysis case is that the oil pressure has a preset positive correlation with the A annulus, indicating that the oil pipe may leak; in this analysis case, it is necessary to check the relationship between the oil pressure and the A annulus pressure to further confirm the integrity of the oil pipe; The condition of the fourth analysis case is that the pressure of the annulus A is greater than the mean value plus two times the standard deviation, indicating that the pressure of the annulus A is too high and the probability of integrity failure is high; in this analysis case, special attention should be paid to the pressure change of the annulus A to further evaluate the integrity status of the wellbore; When the condition of the fifth analysis case is that the conditions of the first to fourth analysis cases are not met, it indicates that there is no integrity problem with the wellbore; in this analysis case, it is necessary to continue to monitor various indicators of the wellbore to ensure that they remain within the normal range.

[0012] Furthermore, the inductive decision tree model is used to comprehensively analyze the chemical composition changes of the fluid in the wellbore to be evaluated, the risk level of the fluid in the wellbore to be evaluated, and the real-time acquired data of the wellbore to be evaluated to obtain the current integrity status of the wellbore to be evaluated. If there is a potential risk in the wellbore to be evaluated, an early warning is issued, including: The inductive decision tree model compares the chemical composition changes of the fluid in the wellbore to be evaluated, the risk level of the fluid in the wellbore to be evaluated, and the data of the wellbore to be evaluated with various integrity problems that may occur in the wellbore to generate a decision path; The inductive decision tree model determines the current integrity status of the wellbore to be evaluated based on the decision path; Optimize the inductive decision tree model based on historical data and real-time feedback data; When it is detected that the current integrity status of the wellbore to be assessed presents a pre-set potential risk, a corresponding warning is issued and the required maintenance or repair recommendations are given.

[0013] In a second aspect, a wellbore integrity assessment system is provided, comprising: A real-time chemical analysis module is used to detect the chemical composition changes of the fluid in the wellbore to be evaluated using the Duval triangle method, determine the risk level of the fluid in the wellbore to be evaluated, and determine the analysis status under different risk levels; The inductive decision tree analysis module is used to use the inductive decision tree model to comprehensively analyze the changes in the chemical composition of the fluid in the wellbore to be evaluated, the risk level of the fluid in the wellbore to be evaluated, and the real-time data of the wellbore to be evaluated, so as to obtain the current integrity status of the wellbore to be evaluated, and issue an early warning if there is a potential risk in the wellbore to be evaluated.

[0014] In a third aspect, a processing device is provided, comprising computer program instructions, wherein the computer program instructions are used to implement the steps corresponding to the above-mentioned wellbore integrity assessment method when executed by the processing device.

[0015] In a fourth aspect, a computer-readable storage medium is provided, on which computer program instructions are stored, wherein the computer program instructions, when executed by a processor, are used to implement the steps corresponding to the above-mentioned wellbore integrity assessment method.

[0016] The present invention adopts the above technical solution, which has the following advantages: 1. Enhanced sensitivity and diagnostic capability: The present invention analyzes the chemical composition of the fluid inside the wellbore, especially the different types of gas components, through the Duval triangle method, and can accurately identify the changes in the chemical composition of the wellbore fluid, especially the changes in the gas composition, which is crucial for the early identification of small cracks or corrosion in the wellbore. The present invention can promptly detect possible structural problems in the wellbore by monitoring these chemical changes in real time. This method has shown efficient identification and classification capabilities in diagnosing power transformer faults and is expected to be equally effective in wellbore integrity detection.

[0017] 2. Comprehensive data collection and processing: Another key point of the present invention is to comprehensively collect various wellbore data (including pressure, temperature, fluid chemical composition, etc.) and use inductive decision tree technology for efficient processing and analysis. Through this method, not only a single type of data can be analyzed, but also multiple data types can be integrated to provide more comprehensive wellbore integrity information.

[0018] 3. Efficient data processing and analysis: The present invention uses inductive decision trees to process and analyze large amounts of complex data from wellbores. It can not only process complex and multidimensional data sets, but also generate easy-to-understand classification rules. By inductive decision trees, the integrity of the wellbore can be accurately diagnosed and potential future risks can be predicted. This method has been proven to be effective in processing complex data and generating easy-to-understand classification rules in power transformer fault diagnosis.

[0019] 4. Predicting future potential risks: The present invention combines the Duval Triangle method and the inductive decision tree method, which can not only identify current wellbore integrity issues, but also predict future potential risks based on data analysis, so as to take preventive measures in advance.

[0020] 5. Self-learning and continuous optimization: The present invention has the ability of self-learning and can continuously optimize the inductive decision tree model based on historical data and real-time feedback, which means that the detection and prediction capabilities will continue to improve over time.

[0021] In summary, the wellbore integrity detection system of the present invention is intended to overcome the limitations of traditional methods and improve the safety and operational efficiency of oil wells through efficient and accurate diagnostic methods. BRIEF DESCRIPTION OF THE DRAWINGS

[0022] Various other advantages and benefits will become apparent to those of ordinary skill in the art by reading the detailed description of the preferred embodiments below. The accompanying drawings are only for the purpose of illustrating the preferred embodiments and are not to be considered as limiting the present invention. Throughout the accompanying drawings, the same reference numerals are used to represent the same components. In the accompanying drawings: Figure 1 It is a schematic diagram of the structure of the method flow provided by an embodiment of the present invention; Figure 2 It is a schematic diagram of the quality assessment of the wellbore cement sheath based on the Duval triangle provided by an embodiment of the present invention; Figure 3 It is a schematic diagram of the system structure provided by an embodiment of the present invention. DETAILED DESCRIPTION

[0023] The exemplary embodiments of the present invention will be described in more detail below with reference to the accompanying drawings. Although the exemplary embodiments of the present invention are shown in the accompanying drawings, it should be understood that the present invention can be implemented in various forms and should not be limited by the embodiments described herein. On the contrary, these embodiments are provided in order to enable a more thorough understanding of the present invention and to fully convey the scope of the present invention to those skilled in the art.

[0024] It should be understood that the terms used herein are only for the purpose of describing specific example embodiments and are not intended to be limiting. Unless the context clearly indicates otherwise, the singular forms "one", "an" and "said" as used herein may also be meant to include plural forms. The terms "include", "comprise", "contain", and "have" are inclusive, and therefore specify the existence of stated features, steps, operations, elements and / or parts, but do not exclude the existence or addition of one or more other features, steps, operations, elements, parts, and / or combinations thereof. The method steps, processes, and operations described herein are not interpreted as necessarily requiring them to be performed in the specific order described or illustrated, unless the execution order is clearly indicated. It should also be understood that additional or alternative steps may be used.

[0025] Although the terms first, second, third, etc. can be used in the text to describe multiple elements, components, regions, layers and / or sections, these elements, components, regions, layers and / or sections should not be limited by these terms. These terms can only be used to distinguish an element, component, region, layer or section from another region, layer or section. Unless the context clearly indicates, terms such as "first", "second" and other numerical terms do not imply order or sequence when used in the text. Therefore, the first element, component, region, layer or section discussed below can be referred to as the second element, component, region, layer or section without departing from the teaching of the example embodiments.

[0026] Existing methods for evaluating wellbore integrity face multiple challenges, the core problem being that they cannot provide real-time, comprehensive, and accurate monitoring of wellbore status. First, conventional chemical analysis methods rely on offline sampling and laboratory testing. Although this method can provide some chemical information, it may miss early minor damage or changes in the wellbore due to the inability to monitor in real time. Second, although physical sensors such as pressure and temperature sensors can provide real-time data, they often cannot be directly associated with specific problems in the structural integrity of the wellbore, and their long-term stability and accuracy in the harsh downhole environment may be affected. In addition, although acoustic and ultrasonic methods can detect cracks and corrosion in the wellbore wall, their detection accuracy is limited in complex downhole environments, multiphase flow, and high noise conditions. At the same time, high-resolution cameras and image recognition methods may not provide high-quality images in multiphase flow or harsh environments, thus limiting their application in wellbore integrity monitoring. Finally, although predictive maintenance models based on historical data can predict potential problems, these models may have limitations in interpreting data and providing specific structural integrity information. In summary, existing technologies have obvious shortcomings in providing real-time, accurate, and comprehensive wellbore integrity assessments. Based on this, the present invention provides a wellbore integrity assessment method, comprising: using the Duval triangle method to detect the chemical composition changes of the fluid in the wellbore to be assessed, determining the risk level of the fluid in the wellbore to be assessed, and determining the analysis conditions under different risk levels; using an inductive decision tree model to comprehensively analyze the chemical composition changes of the fluid in the wellbore to be assessed, the risk level of the fluid in the wellbore to be assessed, and the real-time acquired data of the wellbore to be assessed, so as to obtain the current integrity status of the wellbore to be assessed, and if there is a potential risk in the wellbore to be assessed, an early warning is issued.

[0027] Application of Duval Triangle: This method is used in power transformer fault diagnosis to effectively diagnose and classify fault types by analyzing the combustible gas composition in transformer oil. In the present invention, Duval Triangle is applied to wellbore integrity detection to analyze the chemical composition of the fluid in the wellbore, especially the changes in gas composition, which may indicate structural problems in the wellbore, such as cracks or corrosion.

[0028] Integration of inductive decision trees: Inductive decision trees have significant advantages in data processing and analysis, especially when dealing with complex data sets. In the present invention, a decision tree model is used to analyze and process various data collected from the wellbore, including pressure, temperature, chemical composition analysis, etc. These data are used to construct decision paths to diagnose and classify the integrity status of the wellbore.

[0029] Comprehensive multi-source data analysis: This invention combines the chemical analysis capabilities of Duval’s triangulation method with the data processing capabilities of inductive decision trees. First, the chemical composition of the fluid in the wellbore is analyzed by Duval’s triangulation method, while other key data such as wellbore pressure and temperature are collected. Subsequently, these comprehensive data are deeply analyzed using inductive decision trees to identify possible wellbore integrity issues.

[0030] Improved accuracy and comprehensiveness of diagnosis: The present invention not only improves the accuracy of diagnosis, but also increases the comprehensiveness of the assessment. The Duval Triangle provides a sensitive analytical means for chemical composition, while the inductive decision tree allows for efficient classification and analysis of multidimensional data from the wellbore, thereby ensuring timely and comprehensive identification of wellbore integrity issues.

[0031] This comprehensive analysis method can not only improve the efficiency of data processing, but also enhance the ability to predict potential risks in the future. In addition, the real-time monitoring and prediction functions of the present invention enable operators to take preventive measures in a timely manner, thereby effectively preventing potential catastrophic events. Through its innovative real-time chemical analysis, comprehensive data processing capabilities, and forward-looking monitoring and prediction capabilities, the present invention successfully overcomes the limitations of existing technologies in real-time monitoring, data interpretation, accuracy, and prediction capabilities. It not only provides more reliable and efficient technical support for the safe operation of oil wells, but also improves the intelligent level of the entire oilfield management, laying a solid technical foundation for the future development of the oil and gas industry.

[0032] Example 1 like Figure 1 As shown, this embodiment provides a wellbore integrity assessment method, comprising the following steps: 1) Use the Duval triangle method to detect changes in the chemical composition of the fluid in the wellbore to be evaluated, determine the risk level of the fluid in the wellbore to be evaluated, and determine the analysis conditions under different risk levels. When the fluid passes through the wellbore, the chemical composition may change due to cracks or corrosion. These changes will be detected and analyzed in real time by the Duval triangle method, so as to quickly discover possible structural problems in the wellbore cement sheath. The specific process of this step is: 1.1) If Figure 2 As shown, the Duval triangle method is used to detect the changes in the chemical composition of the fluid in the wellbore to be evaluated.

[0033] Specifically, the fluid in the wellbore to be evaluated refers to all possible fluids flowing in the wellbore, including oil, gas, water, etc. Specifically, the fluid inside the wellbore may include various chemical substances that may penetrate or accumulate near the cement sheath. The "fluid" in this embodiment refers to the fluid present in the wellbore annulus or inside the wellbore, and is not limited to the cement sheath itself.

[0034] Specifically, in this embodiment, the Duval triangle method used is mainly used to analyze the chemical composition of the fluid in the wellbore, especially focusing on the changes in the gas components in the wellbore. The gas components mentioned mainly include H2S (hydrogen sulfide), CH4 (methane), CO2 (carbon dioxide), etc. These gas components are important indicators of the fluid in the wellbore. By monitoring their concentrations and changing trends, potential risks in the wellbore can be reflected, such as the possibility of corrosion, cracks or casing leakage.

[0035] 1.2) According to the detected chemical composition changes of the fluid in the wellbore to be evaluated and the pre-set cement sheath risk range, determine the risk level of the fluid in the wellbore to be evaluated, including high risk, medium risk, low risk or normal. If the risk level of the fluid in the wellbore to be evaluated is high risk, proceed to step 1.3); if the risk level of the fluid in the wellbore to be evaluated is medium risk, proceed to step 1.4); if the risk level of the fluid in the wellbore to be evaluated is low risk or normal, proceed to step 1.5).

[0036] 1.3) According to the relative pressure change of the AB annulus of the wellbore to be evaluated and the preset relative value of change, determine different analysis situations under high risk level: 1.3.1) Determine the relative pressure change of the AB annulus of the wellbore to be evaluated. If the determined relative pressure change of the AB annulus is lower than the preset relative value, proceed to step 1.3.2); otherwise, obtain analysis case 1.

[0037] Specifically, the conditions for case 1 are that there is a large positive correlation between annulus A and annulus B (for example, greater than 0.5), and the pressures of annulus A and annulus B are both higher than the average, indicating that the isolation valve of the wellbore to be evaluated may fail or the casing may leak. In this analysis, it is necessary to further check the pressure changes of annulus A and annulus B, and whether the wellbore temperature exceeds the normal range to confirm whether there is a leakage problem.

[0038] 1.3.2) Measure the wellbore temperature of the wellbore to be evaluated. If the measured wellbore temperature exceeds a preset temperature critical value, analysis case 2 is obtained; otherwise, analysis case 3 is obtained.

[0039] Specifically, the condition for case 2 is that the pressure of annulus B is greater than 0.69 MPa, indicating that the cementing quality is poor or the casing is leaking. In this case, it is necessary to further check the pressure change of annulus B and the overall condition of the wellbore, such as whether there are signs of leakage.

[0040] Specifically, the condition of case 3 is that the oil pressure has a large positive correlation with the A annulus (for example, greater than 0.5), indicating that the tubing may leak. In this analysis case, it is necessary to check the relationship between the oil pressure and the A annulus pressure to further confirm the integrity of the tubing.

[0041] Specifically, in actual operation, the measurement of wellbore temperature is usually carried out through temperature sensors installed in the wellbore, which monitor the temperature changes in the wellbore in real time and transmit the data back to the ground control system. If it is determined in the analysis of case 1 that the wellbore temperature needs to be measured, data can be collected through these sensors and compared with the preset critical value to confirm the integrity status of the wellbore.

[0042] 1.4) According to the relative pressure change of the AB annulus of the wellbore to be evaluated and the preset relative value of change, determine the different analysis situations under the medium risk level: 1.4.1) Determine the relative pressure change of the AB annulus of the wellbore to be evaluated. If the determined relative pressure change of the AB annulus is higher than the preset relative value, proceed to step 1.3.2); otherwise, proceed to step 1.4.2).

[0043] 1.4.2) Measure the oil and gas production of the wellbore to be evaluated. If the measured oil and gas production exceeds the preset oil and gas production critical value, analysis case 4 is obtained; otherwise, analysis case 5 is obtained.

[0044] Specifically, the condition for case 4 is that the pressure in annulus A is greater than the mean plus two standard deviations, indicating that the pressure in annulus A is too high and the probability of integrity failure is high. In this case, special attention should be paid to the pressure changes in annulus A, and the integrity status of the wellbore needs to be further evaluated.

[0045] Specifically, when the conditions of case 5 are not met in case 1 to case 4, the wellbore integrity is in good condition, indicating that there is no obvious integrity problem in the wellbore. In this analysis case, it is necessary to continue to monitor various indicators of the wellbore to ensure that they remain within the normal range.

[0046] 1.5) Based on the CBL logging data of the wellbore to be evaluated, determine the different analysis situations under low risk or normal level: 1.5.1) Analyze CBL logging data for the wellbore to be evaluated.

[0047] 1.5.2) Based on the CBL logging data analysis results, re-evaluate the cement sheath quality. If the cement sheath quality is defective, proceed to step 1.4.1); if the cement sheath quality is normal, proceed to step 1.5.3).

[0048] 1.5.3) Perform a simple assessment of the oil and gas production quality of the wellbore to be assessed. If the oil and gas quality is abnormal, proceed to step 1.4.2); if the oil and gas quality is normal, the analysis of the wellbore to be assessed is normal.

[0049] 2) Use physical sensors to obtain real-time data of the wellbore to be evaluated, including pressure, temperature, and fluid chemical composition.

[0050] 3) Using the inductive decision tree model, a comprehensive analysis is performed on the chemical composition changes of the fluid in the wellbore to be evaluated, the risk level of the fluid in the wellbore to be evaluated, and the data of the wellbore to be evaluated to obtain the current integrity status of the wellbore to be evaluated. If there is a potential risk in the wellbore to be evaluated, an early warning is issued, specifically: 3.1) The inductive decision tree model compares the chemical composition changes of the fluid in the wellbore to be evaluated, the risk level of the fluid in the wellbore to be evaluated, and the data of the wellbore to be evaluated with various integrity problems that may occur in the wellbore to generate a decision path.

[0051] 3.2) Inductive decision tree model Determine the current integrity status of the wellbore to be evaluated based on the decision path.

[0052] Specifically, various integrity problems that may occur in the wellbore include cracks, corrosion or leakage.

[0053] 3.3) The inductive decision tree model is optimized based on historical data and real-time feedback data, which means that the accuracy and efficiency of the inductive decision tree model in detecting and predicting wellbore integrity will continue to improve over time.

[0054] Specifically, historical data refers to all data collected in the past period of time, and real-time feedback data refers to all data collected at the current moment. Based on historical data and real-time feedback data, the inductive decision tree model is continuously optimized so that the inductive decision tree model can more accurately predict the integrity status of the wellbore. The optimization process may include adjusting the structure and weight of the decision tree to adapt to new data and actual conditions.

[0055] 3.4) When the current integrity status of the wellbore to be evaluated is detected to have a pre-set potential risk, a corresponding warning is issued and the required maintenance or repair suggestions are given. For example, if the wellbore to be evaluated is detected to have a leakage risk, the model may recommend that production be stopped immediately and repairs be carried out.

[0056] 4) Visualize the current integrity status of the wellbore to be assessed, early warning of potential risks, and required maintenance or repair recommendations. In this way, operators can gain a comprehensive understanding of the wellbore integrity and take appropriate measures as needed.

[0057] Example 2 like Figure 3 As shown, this embodiment provides a wellbore integrity assessment system, comprising: The real-time chemical analysis module is used to detect the change of chemical composition of the fluid in the wellbore to be evaluated by using the Duval triangle method, determine the risk level of the fluid in the wellbore to be evaluated, and determine the analysis status under different risk levels.

[0058] The data collection module is used to use physical sensors to obtain real-time data of the wellbore to be evaluated, including pressure, temperature, and fluid chemical composition.

[0059] The inductive decision tree analysis module is used to conduct a comprehensive analysis of the changes in the chemical composition of the fluid in the wellbore to be evaluated, the risk level of the fluid in the wellbore to be evaluated, and the real-time data of the wellbore to be evaluated, so as to obtain the current integrity status of the wellbore to be evaluated. If there is a potential risk in the wellbore to be evaluated, an early warning will be issued.

[0060] The visualization module is used to visualize the current integrity status of the wellbore to be assessed, early warning of potential risks, and required maintenance or repair recommendations.

[0061] The system provided in this embodiment is used to execute the above-mentioned method embodiments. Please refer to the above-mentioned embodiments for specific processes and detailed contents, which will not be repeated here.

[0062] Example 3 This embodiment provides a processing device corresponding to the wellbore integrity assessment method provided in Embodiment 1. The processing device can be applicable to a client processing device, such as a mobile phone, a laptop computer, a tablet computer, a desktop computer, etc., to execute the method of Embodiment 1.

[0063] The processing device includes a processor, a memory, a communication interface and a bus, and the processor, the memory and the communication interface are connected through the bus to complete mutual communication. The memory stores a computer program that can be run on the processing device, and the processing device executes the wellbore integrity assessment method provided in this embodiment 1 when running the computer program.

[0064] In some implementations, the memory may be a high-speed random access memory (RAM), and may also include a non-volatile memory, such as at least one disk storage.

[0065] In some other implementations, the processor may be a central processing unit (CPU), a digital signal processor (DSP), or other general-purpose processors of various types, which are not limited herein.

[0066] In addition, the logic instructions in the above-mentioned memory can be implemented in the form of software functional units and can be stored in a computer-readable storage medium when sold or used as an independent product. Based on such an understanding, the technical solution of the present invention can be essentially or partly embodied in the form of a software product that contributes to the prior art. The computer software product is stored in a storage medium, including several instructions for a computer device (which can be a personal computer, a server, or a network device, etc.) to perform all or part of the steps of the method described in each embodiment of the present invention. The aforementioned storage medium includes: U disk, mobile hard disk, read-only memory (ROM, Read-Only Memory), random access memory (RAM, Random Access Memory), disk or optical disk, etc. Various media that can store program codes.

[0067] Those skilled in the art will understand that the structure of the above-mentioned computing device is only a partial structure related to the solution of the present invention, and does not constitute a limitation on the computing device to which the solution of the present invention is applied. The specific computing device may include more or fewer components, or combine certain components, or have a different arrangement of components.

[0068] Example 4 This embodiment provides a computer program product corresponding to the wellbore integrity assessment method provided in Embodiment 1. The computer program product may include a computer-readable storage medium carrying computer-readable program instructions for executing the wellbore integrity assessment method described in Embodiment 1.

[0069] Computer readable storage media can be tangible devices that hold and store instructions used by instruction execution devices. Computer readable storage media can be, for example, but not limited to, electronic storage devices, magnetic storage devices, optical storage devices, electromagnetic storage devices, semiconductor storage devices, or any combination thereof.

[0070] The above embodiment provides a computer-readable storage medium, whose implementation principle and technical effect are similar to those of the above method embodiment, and will not be repeated here.

[0071] 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 flowchart and / or block diagram, as well as the combination of processes and / or blocks in the flowchart and / or block diagram, 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 flowchart and / or block diagram. 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.

[0072] These computer program instructions may also be stored in a computer-readable memory capable of directing a computer or other programmable data processing device to operate 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 A function specified in one or more boxes.

[0073] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operating steps are executed on the computer or other programmable device to produce a computer-implemented process, thereby providing instructions for implementing the process. Figure 1 A process or multiple processes and / or boxes Figure 1 The steps for the functions specified in one or more boxes.

[0074] The above embodiments are only used to illustrate the present invention, wherein the structure, connection mode and manufacturing process of each component may be changed. Any equivalent transformations and improvements based on the technical solution of the present invention should not be excluded from the protection scope of the present invention.

Claims

1. A method for evaluating wellbore integrity, characterized in that: include: The Duval triangle method is used to detect the changes in the chemical composition of the fluid in the wellbore to be evaluated, determine the risk level of the fluid in the wellbore to be evaluated, and determine the analysis conditions under different risk levels; An inductive decision tree model is used to comprehensively analyze the changes in the chemical composition of the fluid in the wellbore to be evaluated, the risk level of the fluid in the wellbore to be evaluated, and the real-time data of the wellbore to be evaluated to obtain the current integrity status of the wellbore to be evaluated. If there is a potential risk in the wellbore to be evaluated, an early warning will be issued.

2. A wellbore integrity assessment method according to claim 1, characterized in that: The Duval triangle method is used to detect the chemical composition changes of the fluid in the wellbore to be evaluated, determine the risk level of the fluid in the wellbore to be evaluated, and determine the analysis conditions under different risk levels, including: 1.1) Use the Duval triangle method to detect the chemical composition changes of the fluid in the wellbore to be evaluated; 1.2) According to the chemical composition changes of the fluid in the wellbore to be evaluated and the pre-set cement sheath risk range, determine the risk level of the fluid in the wellbore to be evaluated, including high risk, medium risk, low risk or normal. If the risk level of the fluid in the wellbore to be evaluated is high risk, proceed to 1.3); if the risk level of the fluid in the wellbore to be evaluated is medium risk, proceed to 1.4); if the risk level of the fluid in the wellbore to be evaluated is low risk or normal, proceed to 1.5); 1.3) Determine different analysis situations under high risk level according to the relative pressure change of the AB annulus of the wellbore to be evaluated and the preset relative value of change; 1.4) Determine different analysis situations under medium risk level according to the relative pressure change of the AB annulus of the wellbore to be evaluated and the preset relative value of change; 1.5) Based on the CBL logging data of the wellbore to be evaluated, determine different analysis situations under low risk or normal level.

3. A wellbore integrity assessment method according to claim 2, characterized in that: According to the relative pressure change of the AB annulus of the wellbore to be evaluated and the preset relative value of the change, different analysis situations under high risk levels are determined, including: 1.3.1) Determine the relative pressure change of the AB annulus of the wellbore to be evaluated. If the determined relative pressure change of the AB annulus is lower than the preset relative value, proceed to 1.3.2); otherwise, obtain the first analysis situation; 1.3.2) Measure the wellbore temperature of the wellbore to be evaluated. If the measured wellbore temperature exceeds a preset temperature critical value, a second analysis situation is obtained; otherwise, a third analysis situation is obtained.

4. A wellbore integrity assessment method according to claim 3, characterized in that the step of determining different analysis situations at a medium risk level according to the relative pressure change of the AB annulus of the wellbore to be assessed and a preset relative value of the change comprises: 1.4.1) Determine the relative pressure change of the AB annulus of the wellbore to be evaluated. If the determined relative pressure change of the AB annulus is higher than the preset relative value, proceed to 1.3.2); otherwise, proceed to 1.4.2); 1.4.2) Measure the oil and gas production of the wellbore to be evaluated. If the measured oil and gas production exceeds a preset oil and gas production critical value, a fourth analysis situation is obtained; otherwise, a fifth analysis situation is obtained.

5. A wellbore integrity assessment method according to claim 4, characterized in that: According to the CBL logging data of the wellbore to be evaluated, different analysis situations at low risk or normal level are determined, including: 1.5.1) Analyze CBL logging data for the wellbore to be evaluated; 1.5.2) Based on the CBL logging data analysis results, re-evaluate the cement sheath quality. If the cement sheath quality is defective, proceed to 1.4.1); if the cement sheath quality is normal, proceed to 1.5.3); 1.5.3) Perform a simple assessment of the oil and gas production quality of the wellbore to be assessed. If the oil and gas quality is abnormal, proceed to 1.4.2); if the oil and gas quality is normal, the analysis of the wellbore to be assessed is normal.

6. A wellbore integrity assessment method according to claim 5, characterized in that: The condition of the first analysis case is that there is a preset positive correlation between annulus A and annulus B, and the pressure of annulus A and annulus B are both higher than the average value, indicating that the isolation valve of the wellbore to be evaluated may fail or the casing may leak. In this analysis case, it is necessary to further check the pressure changes of annulus A and annulus B, and whether the wellbore temperature exceeds the normal range; The condition of the second analysis situation is that the pressure of the B annulus is greater than a preset value, indicating that the cementing quality is poor or the casing is leaking; in this analysis situation, it is necessary to further check the pressure change of the B annulus and the overall condition of the wellbore; The condition of the third analysis case is that the oil pressure has a preset positive correlation with the A annulus, indicating that the oil pipe may leak; in this analysis case, it is necessary to check the relationship between the oil pressure and the A annulus pressure to further confirm the integrity of the oil pipe; The condition of the fourth analysis case is that the pressure of the annulus A is greater than the mean value plus two times the standard deviation, indicating that the pressure of the annulus A is too high and the probability of integrity failure is high; in this analysis case, special attention should be paid to the pressure change of the annulus A to further evaluate the integrity status of the wellbore; When the condition of the fifth analysis case is that the conditions of the first to fourth analysis cases are not met, it indicates that there is no integrity problem with the wellbore; in this analysis case, it is necessary to continue to monitor various indicators of the wellbore to ensure that they remain within the normal range.

7. A wellbore integrity assessment method according to claim 1, characterized in that: The inductive decision tree model is used to comprehensively analyze the chemical composition changes of the fluid in the wellbore to be evaluated, the risk level of the fluid in the wellbore to be evaluated, and the real-time acquired data of the wellbore to be evaluated, so as to obtain the current integrity status of the wellbore to be evaluated. If there is a potential risk in the wellbore to be evaluated, an early warning is issued, including: The inductive decision tree model compares the chemical composition changes of the fluid in the wellbore to be evaluated, the risk level of the fluid in the wellbore to be evaluated, and the data of the wellbore to be evaluated with various integrity problems that may occur in the wellbore to generate a decision path; The inductive decision tree model determines the current integrity status of the wellbore to be evaluated based on the decision path; Optimize the inductive decision tree model based on historical data and real-time feedback data; When it is detected that the current integrity status of the wellbore to be assessed presents a pre-set potential risk, a corresponding warning is issued and the required maintenance or repair recommendations are given.

8. A wellbore integrity assessment system, characterized in that: include: A real-time chemical analysis module is used to detect the chemical composition changes of the fluid in the wellbore to be evaluated using the Duval triangle method, determine the risk level of the fluid in the wellbore to be evaluated, and determine the analysis status under different risk levels; The inductive decision tree analysis module is used to use the inductive decision tree model to comprehensively analyze the changes in the chemical composition of the fluid in the wellbore to be evaluated, the risk level of the fluid in the wellbore to be evaluated, and the real-time data of the wellbore to be evaluated, so as to obtain the current integrity status of the wellbore to be evaluated, and issue an early warning if there is a potential risk in the wellbore to be evaluated.

9. A processing device, characterized in that: The method comprises computer program instructions, wherein the computer program instructions are used to implement the steps corresponding to the wellbore integrity assessment method according to any one of claims 1 to 7 when executed by a processing device.

10. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores computer program instructions, wherein the computer program instructions are used to implement the steps corresponding to the wellbore integrity assessment method according to any one of claims 1 to 7 when executed by a processor.

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