Carbon dioxide geological storage wellbore integrity assessment method and device, storage medium

Abstract

The present application discloses a method and device for evaluating the integrity of a carbon dioxide geological storage wellbore, a storage medium and an electronic device. The method comprises: determining first data of the wellbore where the injection well is located when it is in a non-working state, wherein the first data is the wellbore integrity data of the injection well determined by a first evaluation method in a first cycle; determining second data of the wellbore where the injection well is located when it is in a working state, wherein the second data is the wellbore integrity data of the injection well determined by a second evaluation method in a second cycle; determining target characteristics of the wellbore based on the first data and the second data; and when determining the formation characteristics corresponding to the current position of the injection well, evaluating the wellbore integrity corresponding to the injection well in a third cycle based on the target characteristics and the formation characteristics to obtain a parameter value reflecting the wellbore integrity.

Description

Technical Field

[0001] The present application relates to the field of carbon dioxide storage monitoring, and more specifically, to a method and device for evaluating the integrity of a carbon dioxide geological storage wellbore, and a storage medium. Background Art

[0002] Carbon dioxide is considered to be one of the main greenhouse gases causing global climate change. At present, countries around the world are working hard to reduce carbon dioxide emissions. A common method is to capture carbon dioxide from emission sources through carbon capture and storage technology, and then seal it in underground storage space. When implementing the carbon dioxide utilization and storage (CCUS) technology application project, during the process of injecting carbon dioxide into the wellbore, if the pipe or cement ring is corroded or other reasons cause the integrity of the wellbore to be destroyed and fail, it will cause carbon dioxide to leak into the formation and even flow into the atmosphere, greatly affecting the carbon dioxide storage efficiency and safety. Therefore, only by evaluating the integrity status of the injection wellbore and doing a good job of wellbore corrosion protection and wellbore integrity monitoring can the integrity of the injection wellbore be evaluated and the safety of the injected carbon dioxide storage be ensured.

[0003] With regard to the problem that existing carbon sequestration technologies cannot efficiently evaluate, monitor and adjust the wellbore integrity of injection wells under different working conditions, no effective solution has been proposed so far.

[0004] Therefore, it is necessary to improve the existing related technologies to overcome the above-mentioned defects in the related technologies and meet the needs of current actual production. Summary of the invention

[0005] The embodiments of the present application provide a method and device for evaluating the wellbore integrity of carbon dioxide geological storage, and a storage medium, so as to at least solve the problem in the existing carbon storage related technologies that it is impossible to efficiently evaluate, monitor, and adjust the wellbore integrity of the injection well under different working conditions.

[0006] According to one aspect of an embodiment of the present application, a method for assessing the integrity of a wellbore for geological storage of carbon dioxide is provided, comprising: determining first data of the wellbore in which an injection well is located when it is in a non-working state, wherein the first data is the wellbore integrity data of the injection well determined by a first assessment method in a first cycle; determining second data of the wellbore in which the injection well is located when it is in a working state, wherein the second data is the wellbore integrity data of the injection well determined by a second assessment method in a second cycle; wherein the first cycle and the second cycle are adjacent in time and have the same cycle size, the first assessment method is a static assessment method, and the second assessment method is a dynamic assessment method; determining target characteristics of the wellbore based on the first data and the second data; and when determining the formation characteristics corresponding to the current position of the injection well, assessing the wellbore integrity of the injection well corresponding to the third cycle based on the target characteristics and the formation characteristics, to obtain a parameter value reflecting the wellbore integrity.

[0007] In an exemplary embodiment, determining first data of a wellbore where an injection well is located when the injection well is in a non-working state includes: using a preset tubing damage evaluation process to determine first detection data of a wellbore casing corresponding to the injection well; and using a preset cement ring evaluation process to determine second detection data of a wellbore cement corresponding to the injection well; performing data cleaning on the first detection data and the second detection data to obtain first cleaning data and second cleaning data; and associating the first cleaning data and the second cleaning data to obtain first data.

[0008] In an exemplary embodiment, determining the second data of the wellbore where the injection well is located when it is in a working state includes: using a preset target logging process to determine the third detection data corresponding to the injection well; determining the fourth detection data according to the injection parameters corresponding to the injection well when it is in a working state, wherein the injection parameters include at least one of the following: injection pressure, injection temperature, injection flow rate, injection time, and total injection volume; performing data cleaning on the third detection data and the fourth detection data to obtain third cleaning data and fourth cleaning data; associating the third cleaning data with the fourth cleaning data to obtain second data.

[0009] In an exemplary embodiment, when determining the formation characteristics corresponding to the current position of the injection well, before evaluating the parameter value corresponding to the wellbore integrity of the injection well in the third period based on the target characteristics and the formation characteristics, the above method also includes: collecting real-time monitoring information fed back by the formation monitoring equipment in the injection well; parsing the real-time monitoring information to determine the physical parameters corresponding to the injection well at the formation, wherein the physical parameters include at least: formation depth, formation thickness, formation porosity, formation permeability; determining the formation characteristics corresponding to the current position of the injection well based on the physical parameters.

[0010] In an exemplary embodiment, after evaluating the wellbore integrity of the injection well corresponding to the third period based on the target characteristics and the formation characteristics to obtain a parameter value reflecting the wellbore integrity, the method further includes: when the parameter value is greater than a preset value, determining that the integrity of the injection well meets the continuous injection requirements, allowing the injection well to operate normally within the third period; when the parameter value is less than or equal to the preset value, determining that the integrity of the injection well does not meet the continuous injection requirements, prohibiting the injection well from operating in the third period, and adding an abnormality mark indicating that the integrity is abnormal to the injection well.

[0011] In an exemplary embodiment, after determining that the integrity of the injection well does not meet the continuous injection requirements and prohibiting the injection well from operating in the third cycle, the method further includes: sending an alarm message to a management object associated with the injection well, wherein the alarm message is used to indicate that there is a leakage risk in the current injection well and instruct the management object to initiate target monitoring of the injection well; receiving monitoring data uploaded by the management object in response to the alarm message, wherein the monitoring data is used to indicate result data of processing the injection well by leak detection and logging means corresponding to target monitoring; and when the monitoring data meets the preset monitoring data standard, updating the abnormal flag corresponding to the injection well to a normal flag with normal integrity.

[0012] In an exemplary embodiment, the method further includes: determining a first value corresponding to the injection well in a first period, wherein the first value is used to reflect the wellbore integrity when the injection well is in a non-working state; determining a second value corresponding to the injection well in a second period, wherein the second value is used to reflect the wellbore integrity when the injection well is in a working state; calculating a first difference between the first value and the parameter value, and calculating a second difference between the second value and the parameter value; determining a changing trend of the wellbore integrity corresponding to the injection well based on the first difference and the second difference, so as to evaluate the service life of the injection well based on the changing trend.

[0013] According to another aspect of an embodiment of the present application, a device for evaluating the integrity of a wellbore for geological storage of carbon dioxide is provided, comprising: a first determination module for determining first data of a wellbore in which an injection well is located when the injection well is in a non-working state, wherein the first data is the wellbore integrity data of the injection well determined by using a first evaluation method in a first cycle; a second determination module for determining second data of the wellbore in which the injection well is located when the injection well is in a working state, wherein the second data is the wellbore integrity data of the injection well determined by using a second evaluation method in a second cycle; wherein the first cycle is adjacent to the second cycle in time and has the same cycle size, the first evaluation method is a static evaluation method, and the second evaluation method is a dynamic evaluation method; a third determination module for determining a target feature of the wellbore based on the first data and the second data; an evaluation module for evaluating the wellbore integrity corresponding to the injection well in the third cycle based on the target feature and the formation feature when determining the formation feature corresponding to the current position of the injection well, and obtaining a parameter value reflecting the wellbore integrity.

[0014] According to another aspect of the embodiment of the present application, a computer-readable storage medium is provided, in which a computer program is stored, wherein the computer program is configured to execute the wellbore integrity assessment method when running.

[0015] According to another aspect of an embodiment of the present application, an electronic device is provided, including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the wellbore integrity assessment method through the computer program.

[0016] According to another aspect of the embodiment of the present application, a computer program product is also provided, including a computer program, and the computer program is executed by a processor to perform the wellbore integrity assessment method.

[0017] Through this application, the injection well is evaluated in the first cycle using the first evaluation method to obtain the first data, and the injection well is evaluated in the second cycle using the second evaluation method to obtain the second data; the target characteristics corresponding to the injection well in different states are evaluated based on the first data and the second data, and then, knowing the formation characteristics corresponding to the current position of the injection well, the wellbore integrity of the injection well in the third cycle is comprehensively evaluated based on the formation characteristics and the target characteristics, thereby ensuring the effective confirmation of the wellbore integrity during the continuous injection process, and further avoiding injection failures caused by abnormal wellbore integrity. The above technical solution solves the problem that the existing carbon sequestration related technology cannot realize efficient evaluation, monitoring, and adjustment of the wellbore integrity of the injection well under different working conditions, and then improves the operation efficiency and safety of the injection well by dynamically adjusting the injection parameters of the injection well. BRIEF DESCRIPTION OF THE DRAWINGS

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

[0019] In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, the drawings required for use in the embodiments or the description of the prior art will be briefly introduced below. Obviously, for ordinary technicians in this field, other drawings can be obtained based on these drawings without paying any creative labor.

[0020] Figure 1 It is a hardware structure block diagram of an electronic device for a method for evaluating wellbore integrity of geological storage of carbon dioxide according to an embodiment of the present application;

[0021] Figure 2 is a flow chart of a method for evaluating wellbore integrity of geological storage of carbon dioxide according to an embodiment of the present application;

[0022] Figure 3 is a structural schematic diagram of a wellbore integrity target monitoring system according to an embodiment of the present application;

[0023] Figure 4 is a flow chart of a wellbore integrity target monitoring method according to an embodiment of the present application;

[0024] Figure 5 It is a structural block diagram of a carbon dioxide geological storage wellbore integrity assessment device according to an embodiment of the present application. DETAILED DESCRIPTION

[0025] In order to enable those skilled in the art to better understand the solution of the present application, the technical solution in the embodiments of the present application will be clearly and completely described below in conjunction with the drawings in the embodiments of the present application. Obviously, the described embodiments are only part of the embodiments of the present application, not all of the embodiments. Based on the embodiments in the present application, all other embodiments obtained by ordinary technicians in this field without creative work should fall within the scope of protection of the present application.

[0026] It should be noted that the terms "first", "second", etc. in the specification and claims of the present application and the above-mentioned drawings are used to distinguish similar objects, and are not necessarily used to describe a specific order or sequence. It should be understood that the data used in this way can be interchangeable where appropriate, so that the embodiments of the present application described herein can be implemented in an order other than those illustrated or described herein. In addition, the terms "including" and "having" and any of their variations are intended to cover non-exclusive inclusions, for example, a process, method, system, product or device comprising a series of steps or units is not necessarily limited to those steps or units clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or devices.

[0027] The method embodiments provided in the embodiments of the present application can be executed in a computer terminal, a mobile terminal, an electronic device or a similar computing device. Taking running on an electronic device as an example, Figure 1 1 is a hardware structure block diagram of an electronic device for a method for evaluating wellbore integrity of geological storage of carbon dioxide in an embodiment of the present application. Figure 1 As shown, the electronic device 10 may include one or more (102a, 102b, ..., 102n are used to illustrate) processors 102 (the processor 102 may include but is not limited to a processing device such as a microprocessor MCU or a programmable logic device FPGA), a memory 104 for storing data, and a transmission device 106 for communication functions. In addition, it may also include: a display, an input / output interface (I / O interface), a universal serial bus (USB) port (which may be included as one of the ports of the BUS bus), a network interface, a power supply and / or a camera. It can be understood by those skilled in the art that Figure 1 The structure shown is only for illustration and does not limit the structure of the above electronic device. Figure 1 More or fewer components as shown, or with Figure 1 Different configurations are shown.

[0028] It should be noted that the one or more processors 102 and / or other data processing circuits described above may generally be referred to herein as "data processing circuits". The data processing circuits may be embodied in whole or in part as software, hardware, firmware, or any other combination thereof. In addition, the data processing circuit may be a single independent processing module, or may be incorporated in whole or in part into any of the other components in the electronic device 10. As described in the embodiments of the present application, the data processing circuit acts as a processor control (e.g., selection of a variable resistor terminal path connected to an interface).

[0029] The memory 104 can be used to store software programs and modules of application software, such as the program instructions / data storage device corresponding to the carbon dioxide geological storage wellbore integrity assessment method in the embodiment of the present application. The processor 102 executes various functional applications and data processing by running the software programs and modules stored in the memory 104, that is, to implement the vulnerability detection method of the above-mentioned application. The memory 104 may include a high-speed random access memory, and may also include a non-volatile memory, such as one or more magnetic storage devices, flash memory, or other non-volatile solid-state memory. In some examples, the memory 104 may further include a memory remotely arranged relative to the processor 102, and these remote memories may be connected to the electronic device 10 via a network. Examples of the above-mentioned network include, but are not limited to, the Internet, an intranet, a local area network, a mobile communication network, and a combination thereof.

[0030] The transmission device 106 is used to receive or send data via a network. The specific example of the above network may include a wireless network provided by a communication provider of the electronic device 10. In one example, the transmission device 106 includes a network adapter (Network Interface Controller, NIC), which can be connected to other network devices through a base station so as to communicate with the Internet. In one example, the transmission device 106 can be a radio frequency (Radio Frequency, RF) module, which is used to communicate with the Internet wirelessly.

[0031] The display may be, for example, a touch screen liquid crystal display (LCD) that may enable a user to interact with a user interface of the electronic device 10 .

[0032] The serial numbers of the above embodiments are only for description and do not represent the advantages or disadvantages of the embodiments.

[0033] In this embodiment, a method for evaluating the integrity of a wellbore for geological storage of carbon dioxide is provided, including but not limited to evaluating the wellbore for injection of supercritical carbon dioxide for storage. Figure 2 is a flow chart of a method for evaluating wellbore integrity of geological storage of carbon dioxide according to an embodiment of the present application. Figure 2 As shown, the process includes the following steps S202-S208:

[0034] Step S202: determining first data of the wellbore where the injection well is located when the injection well is in a non-working state, wherein the first data is the wellbore integrity data of the injection well determined using a first evaluation method within a first cycle;

[0035] Step S204: determining second data of the wellbore where the injection well is located when it is in a working state, wherein the second data is the wellbore integrity data of the injection well determined by using a second evaluation method within a second period; wherein the first period and the second period are adjacent in time and have the same period size, the first evaluation method is a static evaluation method, and the second evaluation method is a dynamic evaluation method;

[0036] It can be understood that the above working state is a state in which the target substance to be injected exists in the injection well, and the non-working state is a state in which the target substance does not exist in the injection well.

[0037] Optionally, the first evaluation method mentioned above has at least two sub-methods, wherein the first sub-method is used to determine the tubing portion corresponding to the injection well according to a preset tubing damage evaluation process, that is, to collect measurement data of pipes made of metal or other materials, and to determine the area where the tubing has abnormalities by analyzing the difference between the data and the standard data corresponding to the tubing when it is not damaged, and to record the corresponding pipeline measurement data. In practical applications, the data collection method for the tubing may include but is not limited to logging technologies such as multi-arm wellbore (MIT), magnetic wall thickness (MTT), and electromagnetic flaw detection (MID-S / K). The first evaluation method mentioned above can be used to determine the corresponding data that can be used to determine the integrity of the wellbore when carbon dioxide is not injected into the injection well. The second sub-method is used to determine the cement portion corresponding to the injection well, that is, the portion between the pipe and the borehole, using a preset cementing cement ring evaluation process. The cement portion is mainly used to fix the tubing and make the injection well a whole.

[0038] Specifically, the cement ring evaluation process includes: according to the current injection well depth and wellhead size, using cement parameters to determine the basic requirements of the sealing performance, pressure resistance, and corrosion resistance of the current cement part, through well logging technology, determining the actual performance of the cement after cementing, comparing the parameters corresponding to the actual performance with the parameters corresponding to the technical requirements, and obtaining the corresponding test data by identifying the cement areas that do not meet the basic requirements.

[0039] For example, in actual use, the cement part is called cement ring. Specifically, the cement ring can be sealed and tested by using technical means such as sector cement bond logging (RBT / SBT) and gamma-density logging (SGDT / AMK2000), or cement can be tested by using IBC and CCFET integrated logging evaluation technology. Then, the test data is collected through the above sub-methods to obtain data that can determine the integrity of the wellbore. Then, based on the collected tubing data and cement data, data that can be used to evaluate the injection well in a non-working state can be obtained. Based on the above collected data, a static pilot evaluation of the wellbore integrity can be performed on the non-working state of the injection well before the injection of carbon dioxide.

[0040] In summary, the above method makes it possible to detect leakage anomalies in the injection well before the injection well is put into operation, thereby ensuring the safety of the subsequent production and sealing process.

[0041] Optionally, the second evaluation method includes but is not limited to logging methods such as well temperature, flow, noise, and pulse neutron oxygen activation, and may also include monitoring of carbon dioxide concentration in the soil near the wellbore and the ground atmosphere near the wellbore, monitoring of soil acidity in the storage area, and other side reactions to the escape of stored carbon dioxide caused by changes in wellbore integrity, thereby obtaining information on changes in the wellbore integrity status. These logging methods and monitoring methods can continuously determine the leakage situation of the current injection well when the injection well is in a state of transmitting injected materials, thereby flexibly determining changes in the current wellbore integrity during material injection. It should be noted that since the injection well has a tubing part and a cement ring, when any one of them leaks, it means that the integrity of the wellbore has changed, but the response sensitivity to the leakage is different. For example, when the tubing part is not damaged but there are cracks in the cement ring, the injection well may be able to operate normally for a period of time. When the target substance corrodes the tubing part, the leakage may be fed back. When the tubing part is directly damaged, the leakage at this time can be effectively identified by monitoring the change in the target substance content between the tubing part and the cement ring. Therefore, in the process of realizing the above-mentioned second evaluation, it is necessary to collect data in real time for evaluation to ensure the timeliness of the evaluation.

[0042] The above-mentioned different collected data can be used to assist in confirming the wellbore integrity corresponding to the injection well in the working state, so as to grasp the changes in the wellbore integrity according to the changes in the data, so that when the wellbore integrity does not meet the integrity requirements, it can be discovered in time, ensuring the safety of subsequent use of the injection well.

[0043] It should be noted that the above cycle can be a time interval of one day, one hour, one week, etc., which is related to the actual storage amount of carbon dioxide processed by the injection well. This application does not make too many restrictions on this.

[0044] Step S206: determining the target feature of the wellbore according to the first data and the second data;

[0045] That is to say, the above method can effectively determine the corrosion state of the injection well pipeline and the outer cement layer of the pipeline when transmitting carbon dioxide to seal the formation, so that the target characteristics reflecting the sealing of the wellbore can be determined. According to the target characteristics, a small amount of data can be used to reflect the changes in the overall sealing condition of the wellbore, so that according to the changes in the target characteristics, it can be known whether there is a probability of leakage in the injection well.

[0046] Optionally, after measurement using the above-mentioned evaluation method, target features such as wellbore material, cement material, and cementing quality that are used to reflect wellbore safety can be determined through data analysis. It should be noted that the above-mentioned target features include but are not limited to the above-mentioned features, which can be determined based on actual feature requirements by processing the collected evaluation data.

[0047] Step S208: When the formation characteristics corresponding to the current position of the injection well are determined, the wellbore integrity corresponding to the injection well in the third period is evaluated based on the target characteristics and the formation characteristics to obtain a parameter value reflecting the wellbore integrity.

[0048] It is understandable that the above-mentioned wellbore integrity is mainly used to reflect whether the structure of the wellbore is intact during the use of the current injection well, that is, no cracks, corrosion or other damage will occur during use, and it can effectively prevent groundwater, carbon dioxide and other substances from leaking to the surface or underground water sources. Then, by ensuring the integrity of the wellbore, environmental pollution in the area where the injection well is located can be effectively avoided, and groundwater resources can be effectively protected to avoid the waste of natural resources.

[0049] In the above steps, the first data is obtained by evaluating the injection well using the first evaluation method in the first cycle, and the second data is obtained by evaluating the injection well using the second evaluation method in the second cycle; the target characteristics corresponding to the injection well in different states are evaluated according to the first data and the second data, and then, knowing the formation characteristics corresponding to the current position of the injection well, the wellbore integrity of the injection well in the third cycle is comprehensively evaluated according to the formation characteristics and the target characteristics, so as to ensure the effective confirmation of the wellbore integrity during the continuous injection process, and further avoid injection failures caused by abnormal wellbore integrity. The above technical solution solves the problem that the existing carbon sequestration related technologies cannot realize efficient evaluation, monitoring, and adjustment of the wellbore integrity of the injection well under different working conditions, and then improves the operation efficiency and safety of the injection well by dynamically adjusting the injection parameters of the injection well.

[0050] In summary, through the above steps, the integrity of the wellbore is damaged and periodic inspections are carried out to avoid failure of downhole equipment, groundwater pollution, and even serious accidents such as wellhead blowouts caused by low wellbore integrity. The risk of wellbore failure is effectively reduced, and the safe operation of injection wells is ensured, thereby improving the efficiency and safety of CO2 storage projects.

[0051] In an exemplary embodiment, determining first data of a wellbore where an injection well is located when the injection well is in a non-working state includes: using a preset tubing damage evaluation process to determine first detection data of a wellbore casing corresponding to the injection well; and using a preset cement ring evaluation process to determine second detection data of a wellbore cement corresponding to the injection well; performing data cleaning on the first detection data and the second detection data to obtain first cleaning data and second cleaning data; and associating the first cleaning data and the second cleaning data to obtain first data.

[0052] Optionally, the data type of the first detection data obtained in the tubing damage assessment process may include but is not limited to the following: Damage degree: such as the degree of rupture of the pipeline, the length and depth of the crack, etc. Damage location: Indicates the specific location where the damage occurs, such as which part of the pipeline is damaged. Damage type: includes different types of damage such as scratches, breakages, corrosion, deformation, etc. Cause of damage: Records possible causes of pipeline damage, such as external damage, internal corrosion, operational errors, etc. Damage size: Measure the size of the damage in order to assess the workload and cost of repairing or replacing the pipeline. Damage impact: Analyze the impact of the damage on pipeline operation and safety, as well as possible countermeasures.

[0053] Optionally, the types of data included in the above-mentioned second detection data may include but are not limited to the following: strength data: including data such as the compressive strength and tensile strength of cement; physical property data: including data such as the density, water absorption rate, and loss on ignition of cement; chemical property data: including data such as the content of various chemical components in cement, pH value, etc.; durability data: including data such as the wear resistance and corrosion resistance of cement.

[0054] In an exemplary embodiment, determining the second data of the wellbore where the injection well is located when it is in a working state includes: using a preset target logging process to determine the third detection data corresponding to the injection well; determining the fourth detection data according to the injection parameters corresponding to the injection well when it is in a working state, wherein the injection parameters include at least one of the following: injection pressure, injection temperature, injection flow rate, injection time, and total injection volume; performing data cleaning on the third detection data and the fourth detection data to obtain third cleaning data and fourth cleaning data; associating the third cleaning data with the fourth cleaning data to obtain second data.

[0055] Optionally, the preset target logging process includes: determining the leak detection technology allowed to be applied to the current injection well, the above leak detection technology includes but is not limited to well temperature, flow, noise, pulse neutron oxygen activation and other logging methods, according to the measurement requirements of the current injection well, using one or more combinations of the above logging methods, collecting measurement parameters of the injection well at preset time intervals, comparing the change size of the same measurement data type according to the preset time length, when the change size exceeds the safety range, summarizing all data corresponding to the measurement data type that exceeds the safety range, and obtaining third detection data, so that during the process of injecting target substances into the injection well, the suspected leakage data of the injection well can also be accurately detected, providing data support for subsequent evaluation.

[0056] The above-mentioned third detection data includes but is not limited to well wall pressure data: the location and degree of well leakage are determined by measuring the pressure changes around the well wall; temperature data: the location and degree of well leakage are determined by measuring the temperature changes inside and outside the well; fluid property data: the type and degree of well leakage are determined by analyzing the property changes of the fluid in the well; sound wave data: the location and degree of well leakage are determined by analyzing the sound wave propagation in the well; resistivity data: the location and degree of well leakage are determined by measuring the resistivity changes around the well wall; seismic data: the location and degree of well leakage are determined by analyzing seismic signals.

[0057] Optionally, the above-mentioned data cleaning includes one of the following contents: Data review: View the overall situation of the data, including data types, missing values, outliers, etc. Data processing: Processing of missing values, outliers and other issues can be done by filling missing values, deleting outliers, etc. Data conversion: Converting data into a format suitable for analysis, including data type conversion, data formatting, etc. Data screening: Filter out required data according to analysis requirements and delete irrelevant data. Data deduplication: Deduplication of data to ensure data uniqueness. Data standardization: Standardize data to ensure data consistency. Data integration: Integrate the cleaned data to form the final data set. Data verification: Verify the cleaned data to ensure that the data quality meets the requirements. Data storage: Store the cleaned data in appropriate media for subsequent analysis.

[0058] In an exemplary embodiment, when determining the formation characteristics corresponding to the current position of the injection well, before evaluating the parameter value corresponding to the wellbore integrity of the injection well in the third period based on the target characteristics and the formation characteristics, the above method also includes: collecting real-time monitoring information fed back by the formation monitoring equipment in the injection well; parsing the real-time monitoring information to determine the physical parameters corresponding to the injection well at the formation, wherein the physical parameters include at least: formation depth, formation thickness, formation porosity, formation permeability; determining the formation characteristics corresponding to the current position of the injection well based on the physical parameters.

[0059] It can be understood that by determining the physical parameters, the changes in the formation during the injection of carbon dioxide into the formation from the injection well can be effectively determined, thereby determining the current safety of carbon dioxide storage, and indirectly reflecting the escape status of carbon dioxide, avoiding subsequent environmental pollution caused by the escape of stored carbon dioxide.

[0060] In an exemplary embodiment, after evaluating the wellbore integrity of the injection well corresponding to the third period based on the target characteristics and the formation characteristics to obtain a parameter value reflecting the wellbore integrity, the method further includes: when the parameter value is greater than a preset value, determining that the integrity of the injection well meets the continuous injection requirements, allowing the injection well to operate normally within the third period; when the parameter value is less than or equal to the preset value, determining that the integrity of the injection well does not meet the continuous injection requirements, prohibiting the injection well from operating in the third period, and adding an abnormality mark indicating that the integrity is abnormal to the injection well.

[0061] In simple terms, after determining the integrity of the current injection through two cycles of data collection, the parameter values ​​corresponding to the wellbore integrity at this time can accurately reflect the corrosion of the current wellbore by the injected carbon dioxide or the crack status of the injection well caused by the environment or usage time. Assuming that the integrity of the wellbore can be set to 100% by default, the current value is 99%, and the alarm threshold is 96%. That is, when a parameter value less than the alarm threshold appears, it means that the injection well at this time has a great risk of leakage. Therefore, it is necessary to identify the abnormality and inform the management object corresponding to the injection well to conduct safety maintenance on the injection well with abnormal integrity in a timely manner, so as to avoid the occurrence of dangerous production incidents caused by the abnormal injection well being put into production.

[0062] In an exemplary embodiment, after determining that the integrity of the injection well does not meet the continuous injection requirements and prohibiting the injection well from operating in the third cycle, the method further includes: sending an alarm message to a management object associated with the injection well, wherein the alarm message is used to indicate that there is a leakage risk in the current injection well and instruct the management object to initiate target monitoring of the injection well; receiving monitoring data uploaded by the management object in response to the alarm message, wherein the monitoring data is used to indicate result data of processing the injection well by leak detection and logging means corresponding to target monitoring; and when the monitoring data meets the preset monitoring data standard, updating the abnormal flag corresponding to the injection well to a normal flag with normal integrity.

[0063] Simply put, since the data obtained through fixed monitoring equipment may have certain errors, in the event of an injection well alarm, secondary confirmation is performed through target monitoring to avoid false data reports.

[0064] In an exemplary embodiment, the method further includes: determining a first value corresponding to the injection well in a first period, wherein the first value is used to reflect the wellbore integrity when the injection well is in a non-working state; determining a second value corresponding to the injection well in a second period, wherein the second value is used to reflect the wellbore integrity when the injection well is in a working state; calculating a first difference between the first value and the parameter value, and calculating a second difference between the second value and the parameter value; determining a changing trend of the wellbore integrity corresponding to the injection well based on the first difference and the second difference, so as to evaluate the service life of the injection well based on the changing trend.

[0065] Optionally, in the above embodiment, the injection well is first evaluated in the first cycle using a static evaluation method, and the first data obtained shows that the wellbore integrity is 100%, and the corresponding first value is 1. The integrity of 100% means that the various parameter values ​​of the injection well are normal, including: injection pressure, injection temperature, injection flow, injection time, injection total volume, etc.; then the injection well is evaluated in the second cycle using a dynamic evaluation method, and the second data obtained shows that the wellbore integrity is 99.5%, and the corresponding second value is 0.995. According to these two sets of data, the integrity change range of the injection well when it changes during the injection process is 0.5%, that is, the first difference is 0 and the second difference is 0.005. Based on this result, the working state of the injection well is evaluated in the third cycle to be carried out, and it is expected that the wellbore integrity will drop to 99%. According to the evaluation results, the injection parameters of the injection well are adjusted to improve the operating efficiency and safety of the injection well. Further, assuming that the minimum value of the integrity is 0.96, according to the decline ratio of 0.005, it is determined that the evaluation can continue to use the injection well for 6 years under the same injection conditions. The above is only an example and does not limit the evaluation process of this application.

[0066] As an optional implementation, the first value can be calculated in the following way: after determining the data of the pipe string part by the first seed method in the first evaluation method, assuming that the pipe string is intact and has no defects and no leakage gaps that meet safety requirements, the corresponding score value is 100; if there are particularly minor defects but do not affect normal use, the corresponding score value is 99; if there are defects but do not affect normal use, the corresponding score value is lower than 99; if there are leakage gaps that meet safety requirements but do not affect normal use, the corresponding score value is higher than the target score corresponding to the alarm threshold and less than 99, which is flexibly determined according to specific circumstances. The value of the cement part can be calculated in the following way: according to other data, it is determined that the impact of carbon dioxide in the surrounding environment of the current injection well on the environment meets the requirements, and the data obtained by the logging method indicates that the current injection well meets production safety, the score value is determined to be 100; otherwise, it is determined that the injection well is abnormal, and the corresponding score value is 0. In summary, assuming that no injection occurs in the injection well, the score of the tubing part is 100, the calculation weight is 50%, the score of the cement part is 100, and the calculation weight is 50%, then the first value = (100*50%+100*50%) ÷ 100 = 1; assuming that injection occurs in the injection well, the score of the tubing part is 99, the calculation weight is 50%, the score of the cement part is 100, and the calculation weight is 50%, the second value = (99*50%+100*50%) ÷ 100 = 0.995. Then, the changes in the above values ​​can clearly know the reasons for the change in wellbore integrity. Thereby reminding relevant personnel to maintain the tubing or cement part. In addition, it should be noted that when it is determined that there is a leak in the tubing, the tubing score is directly adjusted to 0, that is, when the tubing score is lower than the set safety score value, it can be directly determined that the wellbore integrity is abnormal. Or when it is determined that there are dynamically changing leakage gaps or holes in the tubing, the tubing score is adjusted from other values ​​to 0 as soon as it is discovered, thereby achieving safe monitoring of the tubing and managing the impact of tubing changes on the integrity of the current injection wellbore.

[0067] In other words, in order to ensure the practicality of the evaluation results, the wellbore integrity is mainly evaluated through the following two aspects, as follows:

[0068] First, the integrity of the metal casing and cement of the wellbore is scored. Through logging (or other technical means that can detect integrity data) and other technical means, the number of scratches or the degree of damage are scored, and then the integrity and stability of the well wall are evaluated through logging data. For example, in actual applications, the scratches, cracks or other damage of the well wall can be detected through logging instruments (such as acoustic logging, electromagnetic logging, etc.) or other technical means. These data can be used to evaluate the degree of damage to the well wall and score accordingly.

[0069] Specifically, the scoring criteria can be as follows: No damage: The surface of the wellbore is smooth, with no visible scratches or cracks. Score: 100 points. Slight damage: There are a few scratches on the wellbore, but it does not affect the overall stability of the wellbore. Score: 70 points. Moderate damage: There are many scratches on the wellbore, and there may be some small cracks, which require further evaluation. Score: 50 points. Severe damage: There are a large number of scratches and cracks on the wellbore, which may affect the stability of the wellbore and the flow of oil and gas. Score: 30 points. Extreme damage: There are serious cracks and damage on the wellbore, which may require repair or reinforcement. Score: 10 points. These scoring criteria can be adjusted according to specific exploration needs and the actual situation of the wellbore. Through these scores, we can better understand the condition of the wellbore and take corresponding measures to ensure the safety and efficiency of operations.

[0070] On the other hand, in order to detect the working status of the injection well in the sealed state, after injecting gas (such as carbon dioxide gas), it can also be detected according to the amount of leakage of the soil in the formation around the wellbore and the atmosphere near the wellhead, and the score can be judged. The specific implementation process is as follows: Define the standard: First, it is necessary to define the parameters and scoring standards for the test. For example, the maximum allowable concentration of specific pollutants in the soil (such as ppm or mg / kg) and the maximum allowable concentration of specific gases in the atmosphere (such as ppm) can be set. Sampling: Soil and atmosphere sampling is carried out around the wellbore and near the wellhead. Soil sampling may include drilling sampling or surface sampling, while atmospheric sampling may use gas detectors. Analysis: The collected samples are sent to the laboratory for analysis. Soil samples may require chemical analysis to determine the concentration of pollutants, while atmospheric samples may require gas analysis. Evaluation: Based on the analysis results, they are compared with the preset standards. If the pollutant concentration or gas concentration is lower than or equal to the standard value, the test result is considered good; if it exceeds the standard value, further evaluation is required. Scoring: Scoring is performed based on the evaluation results. For example, a system with a full score of 100 can be set up, where: 0-20 points: seriously exceeded, immediate action is required. 21-40 points: exceeded, attention and action is required. 41-60 points: close to the standard, monitoring is required. 61-80 points: good, in line with the standard. 81-100 points: excellent, far below the standard. Record the data, including the sampling location, time, analysis results, evaluation and scoring. For example, if the carbon dioxide concentration in the atmosphere near a wellhead is 5ppm, and the standard value is 10ppm, then this test result can be considered excellent and scored 90 points.

[0071] Obviously, the embodiments described above are only some embodiments of the present application, not all embodiments. In order to better understand the above method, the above process is described below in conjunction with the embodiments, but it is not intended to limit the technical solutions of the embodiments of the present application, specifically:

[0072] The optional embodiment of the present application provides a wellbore integrity target monitoring method to solve the problem that it is impossible to evaluate and adjust the wellbore integrity of the injection well under different working conditions. Based on the previous well logging evaluation of the integrity of the carbon dioxide storage wellbore, the method dynamically obtains the mid- and late-stage leakage monitoring data in real time for analysis, thereby determining the integrity of the current storage wellbore in the current state, and providing support for whether to continue the subsequent injection work.

[0073] Optionally, wellbore integrity is an effective wellbore barrier. Currently, it is widely defined as the pressure bearing capacity and good sealing of the wellbore, good sealing of the wellhead and downhole tools, smooth lifting and lowering of the operating pipe string and tools in the wellbore, and smooth and controllable movement of fluids inside and outside the wellbore. The failure of the pipe string integrity is manifested as leakage of the oil casing due to corrosion, impact, wear and other reasons. The main reasons are, on the one hand, the damage caused to the wellbore by the corrosive solutions, complex injection media and high pressure in the wellbore used in operations such as well drilling, acidizing and fracturing; on the other hand, due to the quality of the casing itself and the lack of force during the operation, the coupling thread is damaged and causes leakage. The failure of the integrity of the cement sheath isolation is manifested as the formation of difficult-to-control crossflow channels, resulting in gas crossflow and abnormal pressure. The main reasons are, on the one hand, the early cementing quality is affected by factors such as cement strength, gas crossflow during cement curing, and construction quality, resulting in channels; on the other hand, the integrity of the cement sheath is damaged by later perforation, fracturing, acidic fluids, abnormal pressure, etc. Whether it is tiny damage like "sand eyes" in the tubing, tiny gaps in the coupling threads, or micro-annular gaps in the cement ring, they can easily lead to serious leakage under the action of wellbore flow pressure.

[0074] Optionally, a static pilot assessment of wellbore integrity can be conducted before CO2 injection. Logging techniques such as multi-arm wellbore diameter (MIT), magnetic wall thickness (MTT), and electromagnetic flaw detection (MID-S / K) can be used to evaluate pipe string damage. Sector cement bond logging (RBT / SBT), gamma-density logging (SGDT / AMK2000) and other technical means can be used to detect cement ring sealing, or IBC and CCFET integrated logging evaluation technology can be used for comprehensive analysis. Static pilot assessment is to conduct casing damage and cementing quality evaluation logging on the wellbore before CO2 injection. Since it is generally in a state of unpressurized injection and there is no fluid flow, static leak detection and channeling logging methods may not be able to accurately monitor intermittent leaks and minor leaks. When entering the continuous CO2 injection stage, target monitoring is required. For wells with leaks and channeling, target logging methods such as well temperature, flow, noise, and pulsed neutron oxygen activation can be used to detect leaks. Whether it is static leak detection or target detection, there is a problem of timeliness. The permanently installed distributed fiber optic logging method can perform all-weather, full-scale, continuous monitoring and early warning through real-time collection, remote transmission, and intelligent analysis. Collaborating with the ground monitoring system can help the burial and monitoring technology gradually move towards industrialization and efficiency.

[0075] Optional, Figure 3 It is a structural schematic diagram of a wellbore integrity target monitoring system according to an embodiment of the present application; the above system at least includes a sensor module 32, a data acquisition module 34, a data processing module 36, and an alarm module 38.

[0076] Optionally, a sensor module 32 is used to monitor changes in parameters such as pressure, temperature, displacement, etc. inside the wellbore, and usually includes a strain gauge, a pressure sensor, a temperature sensor, etc.;

[0077] Optionally, a data acquisition module 34 is responsible for collecting, storing and transmitting the data collected by the sensor;

[0078] Optionally, a data processing module 36 processes and analyzes the collected data to monitor the integrity of the wellbore in real time;

[0079] Optionally, the alarm module 38 may promptly send out an alarm to notify relevant personnel when an abnormal situation is detected in the wellbore.

[0080] It should be noted that the sensor will be affected by oil, gas, water vapor and other substances inside the wellbore. When installing the sensor, the particularity of the internal environment of the wellbore should be considered and protective measures should be taken. The alarm module needs to set a suitable alarm threshold to ensure that the alarm module can issue an alarm in time when the data is abnormal or exceeds the set range. Check the working status of the alarm module regularly to ensure its normal operation.

[0081] As an optional implementation, Figure 4 : is a flow chart of a wellbore integrity target monitoring method according to an embodiment of the present application, and the specific steps are as follows:

[0082] Step 1: Collect wellbore integrity data. The wellbore integrity data is obtained by running well temperature, flow rate, noise, pulse neutron oxygen activation logging instruments and other equipment to measure during fluid flow;

[0083] Step 2: Target. Analyze the collected data to see if there are any abnormal response change points, and determine the possible leakage points through analysis. Using noise and ultrasonic leak detection logging methods to detect leakage, it is possible to detect leakage as low as a small leakage, for example, it can be a leakage rate of 0.02L / min;

[0084] Step 3: Determine the leakage. Perform multiple point measurements and continuous measurements to determine the location of the leak and the leakage situation;

[0085] Step 4: Periodic analysis. Summarize the wellbore integrity data collected over a period of time and conduct periodic analysis. By analyzing the changing trends and patterns of the data, the early warning and identification capabilities of occasional, intermittent, and multiple leakages in one well can be improved;

[0086] Step 5: Early warning and identification: Based on the results of periodic analysis, early warning and identification of possible leakage are carried out, and timely measures are taken to repair and protect the integrity of the wellbore.

[0087] In summary, the optional embodiments of the present application can obtain various data of the wellbore in a timely manner by collecting wellbore integrity data, including temperature, flow, noise, etc., to provide basic data for subsequent leakage detection and analysis. The target can quickly and accurately find the location where leakage may occur by analyzing the data, and use noise and ultrasonic leak detection and logging methods to detect very small leakage. Through multiple point measurements and continuous measurements, the specific location and leakage of the leak point can be determined to provide specific information for the next step of repair. Periodic analysis can analyze the data over a period of time to find the changing trends and laws of the leakage situation, and improve the early warning and identification capabilities of different types of leakage. Early warning and identification can timely warn of possible leakage situations based on the results of periodic analysis, take timely repair measures, protect the integrity of the wellbore, and avoid further damage. Furthermore, by building a complete wellbore integrity detection system, the state of the wellbore can be monitored comprehensively and timely, the detection and repair efficiency of leakage can be improved, and the integrity and safe operation of the wellbore can be guaranteed.

[0088] Through the description of the above implementation methods, those skilled in the art can clearly understand that the method according to the above embodiment can be implemented by means of software plus a necessary general hardware platform, and of course it 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 the present application, or the part that contributes to the prior art, can be embodied in the form of a software product, which is stored in a storage medium (such as ROM / RAM, disk, CD), and includes a number of instructions for a terminal device (which can be a mobile phone, computer, server, or network device, etc.) to execute the methods of each embodiment of the present application.

[0089] In this embodiment, a carbon dioxide geological storage wellbore integrity assessment device is also provided, which is used to implement the above-mentioned embodiments and preferred embodiments, and the descriptions that have been made will not be repeated. As used below, the term "module" can be a combination of software and / or hardware that implements a predetermined function. Although the devices described in the following embodiments are preferably implemented in software, the implementation of hardware, or a combination of software and hardware, is also possible and conceivable.

[0090] Figure 5 : is a structural block diagram of a carbon dioxide geological storage wellbore integrity assessment device according to an embodiment of the present application, the device comprising:

[0091] A first determination module 52 is used to determine first data of the wellbore where the injection well is located when the injection well is in a non-working state, wherein the first data is the wellbore integrity data of the injection well determined by using a first evaluation method within a first period;

[0092] A second determination module 54 is used to determine second data of the wellbore where the injection well is located when the injection well is in a working state, wherein the second data is the wellbore integrity data of the injection well determined by using a second evaluation method within a second period; wherein the first period and the second period are adjacent in time and have the same period size, the first evaluation method is a static evaluation method, and the second evaluation method is a dynamic evaluation method;

[0093] A third determination module 56, configured to determine a target feature of the wellbore based on the first data and the second data;

[0094] The evaluation module 58 is used to evaluate the wellbore integrity corresponding to the injection well in the third period based on the target characteristics and the formation characteristics when determining the formation characteristics corresponding to the current position of the injection well, and obtain a parameter value reflecting the wellbore integrity.

[0095] The above device uses the first evaluation method to evaluate the injection well in the first cycle to obtain the first data, and uses the second evaluation method to evaluate the injection well in the second cycle to obtain the second data; based on the first data and the second data, the target characteristics corresponding to the injection well in different states are evaluated, and then, knowing the formation characteristics corresponding to the current position of the injection well, the wellbore integrity of the injection well in the third cycle is comprehensively evaluated based on the formation characteristics and the target characteristics, thereby ensuring the effective confirmation of the wellbore integrity during the continuous injection process, and further avoiding injection failures caused by abnormal wellbore integrity. The above technical solution solves the problem that the existing carbon sequestration related technology cannot realize efficient evaluation, monitoring, and adjustment of the wellbore integrity of the injection well under different working conditions, and then improves the operation efficiency and safety of the injection well by dynamically adjusting the injection parameters of the injection well.

[0096] In an exemplary embodiment, the above-mentioned first determination module is also used to determine the first detection data of the wellbore casing corresponding to the injection well by adopting a preset tubing damage evaluation process; and to determine the second detection data of the wellbore cement corresponding to the injection well by adopting a preset cement ring evaluation process; to perform data cleaning on the first detection data and the second detection data to obtain first cleaning data and second cleaning data; and to associate the first cleaning data and the second cleaning data to obtain first data.

[0097] In an exemplary embodiment, the above-mentioned second determination module is also used to determine the third detection data corresponding to the injection well using a preset target logging process; determine the fourth detection data according to the injection parameters corresponding to the injection well when it is in a working state, wherein the injection parameters include at least one of the following: injection pressure, injection temperature, injection flow rate, injection time, and total injection volume; perform data cleaning on the third detection data and the fourth detection data to obtain third cleaning data and fourth cleaning data; associate the third cleaning data with the fourth cleaning data to obtain second data.

[0098] In an exemplary embodiment, the above-mentioned device also includes: a fourth determination module, which is used to collect real-time monitoring information fed back by the formation monitoring equipment in the injection well before evaluating the parameter value corresponding to the wellbore integrity of the injection well in the third period based on the target characteristics and the formation characteristics after determining the formation characteristics corresponding to the current position of the injection well; analyze the real-time monitoring information to determine the physical properties corresponding to the injection well at the formation, wherein the physical properties include at least: formation depth, formation thickness, formation porosity, formation permeability; determine the formation characteristics corresponding to the current position of the injection well based on the physical properties parameters.

[0099] In an exemplary embodiment, the above-mentioned device also includes: a fifth determination module, which is used to evaluate the wellbore integrity corresponding to the injection well in the third period based on the target characteristics and the formation characteristics, and after obtaining the parameter value reflecting the wellbore integrity, if the parameter value is greater than a preset value, determine that the integrity of the injection well meets the continuous injection requirements, and allow the injection well to operate normally in the third period; if the parameter value is less than or equal to the preset value, determine that the integrity of the injection well does not meet the continuous injection requirements, prohibit the injection well from operating in the third period, and add an abnormality mark indicating that the integrity is abnormal for the injection well.

[0100] In an exemplary embodiment, the fifth determination module further includes: an alarm unit, used to determine that the integrity of the injection well does not meet the continuous injection requirements, prohibiting the injection well from operating in the third cycle, and sending an alarm message to the management object associated with the injection well, wherein the alarm message is used to indicate that the current injection well has a leakage risk and instruct the management object to initiate target monitoring of the injection well; receiving monitoring data uploaded by the management object in response to the alarm information, wherein the monitoring data is used to indicate result data of processing the injection well through the leak detection and logging means corresponding to the target monitoring; when the monitoring data meets the preset monitoring data standard, updating the abnormal identification corresponding to the injection well to a normal identification with normal integrity.

[0101] In an exemplary embodiment, the above-mentioned device also includes: a sixth determination module, used to determine a first value corresponding to the injection well in a first period, wherein the first value is used to reflect the wellbore integrity when the injection well is in a non-working state; determine a second value corresponding to the injection well in a second period, wherein the second value is used to reflect the wellbore integrity when the injection well is in a working state; calculate a first difference between the first value and the parameter value, and calculate a second difference between the second value and the parameter value; determine a change trend of the wellbore integrity corresponding to the injection well based on the first difference and the second difference, so as to evaluate the service life of the injection well based on the change trend.

[0102] An embodiment of the present application further provides a computer-readable storage medium, in which a computer program is stored, wherein the computer program is configured to execute the steps of any of the above method embodiments when running.

[0103] Optionally, in this embodiment, the storage medium may be configured to store a computer program for performing the following steps:

[0104] S1, determining first data of the wellbore where the injection well is located when it is in a non-working state, wherein the first data is the wellbore integrity data of the injection well determined using a first evaluation method within a first period;

[0105] S2, determining second data of the wellbore where the injection well is located when it is in a working state, wherein the second data is the wellbore integrity data of the injection well determined by using a second evaluation method within a second period; wherein the first period and the second period are adjacent in time and have the same period size, the first evaluation method is a static evaluation method, and the second evaluation method is a dynamic evaluation method;

[0106] S3, determining the target feature of the wellbore according to the first data and the second data;

[0107] S4. When the formation characteristics corresponding to the current position of the injection well are determined, the wellbore integrity corresponding to the injection well in the third period is evaluated based on the target characteristics and the formation characteristics to obtain a parameter value reflecting the wellbore integrity.

[0108] In an exemplary embodiment, the computer-readable storage medium may include, but is not limited to, various media that can store computer programs, such as a USB flash drive, a read-only memory (ROM), a random access memory (RAM), a mobile hard disk, a magnetic disk or an optical disk.

[0109] For specific examples in this embodiment, reference may be made to the examples described in the above embodiments and exemplary implementation modes, and this embodiment will not be described in detail herein.

[0110] An embodiment of the present application further provides a computer program product, including a computer program, and when the computer program is executed by a processor, the steps in any one of the above method embodiments are performed.

[0111] An embodiment of the present application further provides another computer program product, including a non-volatile computer-readable storage medium, wherein the non-volatile computer-readable storage medium stores a computer program, and when the computer program is executed by a processor, the steps in any of the above method embodiments are implemented.

[0112] An embodiment of the present application further provides an electronic device, including a memory and a processor, wherein a computer program is stored in the memory, and the processor is configured to run the computer program to execute the steps in any one of the above method embodiments.

[0113] Optionally, in this embodiment, the processor may be configured to perform the following steps through a computer program:

[0114] S1, determining first data of the wellbore where the injection well is located when it is in a non-working state, wherein the first data is the wellbore integrity data of the injection well determined using a first evaluation method within a first period;

[0115] S2, determining second data of the wellbore where the injection well is located when it is in a working state, wherein the second data is the wellbore integrity data of the injection well determined by using a second evaluation method within a second period; wherein the first period and the second period are adjacent in time and have the same period size, the first evaluation method is a static evaluation method, and the second evaluation method is a dynamic evaluation method;

[0116] S3, determining the target feature of the wellbore according to the first data and the second data;

[0117] S4. When the formation characteristics corresponding to the current position of the injection well are determined, the wellbore integrity corresponding to the injection well in the third period is evaluated based on the target characteristics and the formation characteristics to obtain a parameter value reflecting the wellbore integrity.

[0118] In an 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.

[0119] For specific examples in this embodiment, reference may be made to the examples described in the above embodiments and exemplary implementation modes, and this embodiment will not be described in detail herein.

[0120] Obviously, those skilled in the art should understand that the above modules or steps of the present application can be implemented by a general computing device, they can be concentrated on a single computing device, or distributed on a network composed of N computing devices, they can be implemented by a program code executable by a computing device, so that they can be stored in a storage device and executed by the computing device, and in some cases, the steps shown or described can be executed in a different order from that here, or they can be made into individual integrated circuit modules, or N of the modules or steps can be made into a single integrated circuit module for implementation. In this way, the present application is not limited to any specific combination of hardware and software.

[0121] The above is only a preferred implementation of the present application. It should be pointed out that for ordinary technicians in this technical field, several improvements and modifications can be made without departing from the principles of the present application. These improvements and modifications should also be regarded as the scope of protection of the present application.

Claims

1. A method for evaluating the integrity of a carbon dioxide geological storage wellbore, characterized in that: include: Determine first data of the wellbore where the injection well is located when it is in a non-working state, wherein the first data is wellbore integrity data of the injection well determined using a first evaluation method within a first cycle; Determine second data of the wellbore where the injection well is located when it is in a working state, wherein the second data is the wellbore integrity data of the injection well determined by using a second evaluation method within a second period; wherein the first period and the second period are adjacent in time and have the same period size, the first evaluation method is a static evaluation method, and the second evaluation method is a dynamic evaluation method; determining a target characteristic of the wellbore based on the first data and the second data; When the formation characteristics corresponding to the current position of the injection well are determined, based on the target characteristics and the formation characteristics, the wellbore integrity corresponding to the injection well in the third period is evaluated to obtain a parameter value of the wellbore integrity; The first data of the wellbore where the injection well is located when it is in a non-working state includes: A preset pipe string damage evaluation process is used to determine first detection data of the wellbore casing corresponding to the injection well; and a preset cementing cement ring evaluation process is used to determine second detection data of the wellbore cementing cement corresponding to the injection well; Cleaning the first detection data and the second detection data to obtain first cleaned data and second cleaned data; Associating the first cleaned data with the second cleaned data to obtain first data; Wherein, determining the second data of the wellbore where the injection well is located when it is in the working state includes: Determine the third detection data corresponding to the injection well by using a preset target logging process, wherein the target logging process is used for indication; Determine fourth detection data according to injection parameters corresponding to the injection well when it is in working state, wherein the injection parameters include at least one of the following: injection pressure, injection temperature, injection flow rate, injection time, and total injection volume; Cleaning the third detection data and the fourth detection data to obtain third cleaned data and fourth cleaned data; The third cleaned data and the fourth cleaned data are associated to obtain second data.

2. The method for evaluating wellbore integrity of carbon dioxide geological storage according to claim 1, characterized in that: In the case of determining the formation feature corresponding to the current position of the injection well, before evaluating the parameter value corresponding to the wellbore integrity of the injection well in the third period based on the target feature and the formation feature, the method further includes: Collecting real-time monitoring information fed back by formation monitoring equipment in the injection well; Analyze the real-time monitoring information to determine the physical property parameters corresponding to the injection well at the formation, wherein the physical property parameters at least include: formation depth, formation thickness, formation porosity, and formation permeability; The formation characteristics corresponding to the current position of the injection well are determined based on the physical property parameters.

3. The method for evaluating wellbore integrity of carbon dioxide geological storage according to claim 1, characterized in that: After evaluating the wellbore integrity of the injection well corresponding to the third period based on the target characteristics and the formation characteristics and obtaining a parameter value reflecting the wellbore integrity, the method further includes: In the case where the parameter value is greater than the preset value, determining that the integrity of the injection well meets the continuous injection requirement, allowing the injection well to operate normally in the third period; When the parameter value is less than or equal to the preset value, it is determined that the integrity of the injection well does not meet the continuous injection requirement, the injection well is prohibited from operating in the third cycle, and an abnormality mark indicating that the integrity is abnormal is added to the injection well.

4. The method for evaluating wellbore integrity of carbon dioxide geological storage according to claim 3, characterized in that: After determining that the integrity of the injection well does not meet the continuous injection requirement and prohibiting the injection well from operating in the third cycle, the method further includes: Sending an alarm message to a management object associated with the injection well, wherein the alarm message is used to indicate that there is a leakage risk in the current injection well and instruct the management object to initiate target monitoring of the injection well; Receiving monitoring data uploaded by the management object in response to the alarm information, wherein the monitoring data is used to indicate result data of processing the injection well by leak detection and logging means corresponding to target monitoring; When the monitoring data meets the preset monitoring data standard, the abnormal identification corresponding to the injection well is updated to a normal identification with normal integrity.

5. The method for evaluating wellbore integrity of carbon dioxide geological storage according to claim 1, characterized in that: The method further comprises: Determine a first value corresponding to the injection well in a first period, wherein the first value is used to reflect the wellbore integrity when the injection well is in a non-working state; Determine a second value corresponding to the injection well in the second period, wherein the second value is used to reflect the wellbore integrity when the injection well is in a working state; Calculating a first difference between the first value and the parameter value, and calculating a second difference between the second value and the parameter value; The variation trend of the wellbore integrity corresponding to the injection well is determined according to the first difference and the second difference, so as to evaluate the service life of the injection well according to the variation trend.

6. A carbon dioxide geological storage wellbore integrity assessment device, characterized in that: include: A first determination module is used to determine first data of a wellbore where the injection well is located when the injection well is in a non-working state, wherein the first data is wellbore integrity data of the injection well determined using a first evaluation method within a first cycle; A second determination module is used to determine second data of the wellbore where the injection well is located when the injection well is in a working state, wherein the second data is the wellbore integrity data of the injection well determined by using a second evaluation method within a second period; wherein the first period and the second period are adjacent in time and have the same period size, the first evaluation method is a static evaluation method, and the second evaluation method is a dynamic evaluation method; a third determination module, configured to determine a target feature of the wellbore based on the first data and the second data; An evaluation module, configured to evaluate the wellbore integrity corresponding to the injection well in the third period based on the target feature and the formation feature, and obtain a parameter value reflecting the wellbore integrity, when the formation feature corresponding to the current position of the injection well is determined; The first determination module is further used to determine the first detection data of the wellbore casing corresponding to the injection well by using a preset pipe string damage evaluation process; and to determine the second detection data of the wellbore cement corresponding to the injection well by using a preset cement ring evaluation process; to perform data cleaning on the first detection data and the second detection data to obtain first cleaning data and second cleaning data; and to associate the first cleaning data with the second cleaning data to obtain first data; The second determination module is also used to determine the third detection data corresponding to the injection well by adopting a preset target logging process; determine the fourth detection data according to the injection parameters corresponding to the injection well when it is in a working state, wherein the injection parameters include at least one of the following: injection pressure, injection temperature, injection flow rate, injection time, and total injection volume; perform data cleaning on the third detection data and the fourth detection data to obtain third cleaning data and fourth cleaning data; and associate the third cleaning data with the fourth cleaning data to obtain second data.

7. A computer-readable storage medium, characterized in that: The computer-readable storage medium includes a stored program, wherein the program executes the method according to any one of claims 1 to 5 when executed.

8. An electronic device comprising a memory and a processor, characterized in that: A computer program is stored in the memory, and the processor is configured to execute the method according to any one of claims 1 to 5 through the computer program.

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