Injection state determination method and device, storage medium and electronic device

Abstract

The invention discloses an injection state determination method and device, a storage medium and an electronic device, and the method comprises the steps: determining a first seismic wave of a target region where a target object is located through a three-dimensional seismic technology under the condition that CO2 is detected to be injected into the target object; determining a first stratum migration degree of the target area according to the first seismic wave; according to the first stratum deviation degree, the injection state of injecting CO2 into the target area at the target moment is determined, the target moment is the next moment of the current moment, and the injection state comprises injection stopping and injection continuing. By means of the method, the problem that in the prior art, the stratum deviation degree cannot be accurately judged, then the time when CO2 injection is stopped cannot be accurately determined, and consequently CO2 leakage is caused can be solved.

Description

Technical Field

[0001] The present application relates to the field of CO2 (carbon dioxide) injection. Specifically, it relates to a method and device for determining an injection state, a storage medium, and an electronic device. Background Art

[0002] Existing technologies have certain limitations in analyzing the degree of formation offset during CO2 injection. Currently, the degree of formation offset is usually detected by methods such as ground penetrating radar technology or geological models and numerical simulations. Ground penetrating radar technology utilizes the characteristics of radar waves propagating underground, and studies the changes in the underground formation structure by analyzing phenomena such as reflection, refraction, and scattering of radar waves in the underground formation. However, ground penetrating radar technology is affected by geological conditions and environmental factors, such as complex formation structures and geological tectonic activities, which in turn affect the accuracy of the results of formation offset. Existing geological models and numerical simulation technologies usually detect formation offset based on simplified geological conditions and assumptions, and may not be able to accurately predict complex phenomena in the actual formation, such as the opening, closing, and fluid flow of fractures, and thus cannot accurately detect the degree of formation offset.

[0003] Regarding the problem of CO2 leakage caused by the inability to accurately judge the degree of formation offset in related technologies and thus unable to accurately determine the moment to stop injecting CO2, no effective solution has been obtained yet. Summary of the Invention

[0004] The present application provides a method and device for determining an injection state, a storage medium, and an electronic device, so as to at least solve the problem of CO2 leakage caused by the inability to accurately judge the degree of formation offset in related technologies and thus unable to accurately determine the moment to stop injecting CO2.

[0005] According to an embodiment of the present application, a method for determining an injection state is provided, including: when it is detected that CO2 is injected into a target object, determining a first seismic wave of a target area where the target object is located by three-dimensional seismic technology; determining a first formation offset degree of the target area according to the first seismic wave; determining an injection state of injecting the CO2 into the target area at a target moment according to the first formation offset degree, where the target moment is the next moment of the current moment, and the injection state includes: stopping injection, continuing injection.

[0006] In an exemplary embodiment, before determining the seismic wave of the target area where the target object is located by three-dimensional seismic technology, the method further includes: determining position information corresponding to the target object, where the position information includes at least one of the following: a first geological feature corresponding to the target object, a provincial boundary situation corresponding to the target object; determining a deployment boundary of the three-dimensional seismic technology according to the position information; determining the target area according to the deployment boundary.

[0007] In an exemplary embodiment, before determining the seismic wave of the target area where the target object is located by three-dimensional seismic technology, the method further includes: when it is detected that CO2 has not been injected into the target object, determining a second seismic wave of the target area by the three-dimensional seismic technology; determining a first seismic time-depth relationship of the target area and a second geological feature of the target area according to the second seismic wave; and determining a second formation offset degree of the target area according to the first seismic time-depth relationship and the second geological feature.

[0008] In an exemplary embodiment, determining a first formation offset degree of the target area according to the first seismic wave includes: determining a second seismic time-depth relationship of the target area and a third geological feature of the target area according to the first seismic wave; determining a change degree of the seismic time-depth relationship of the target area according to the first seismic time-depth relationship and the second seismic time-depth relationship; and determining a change degree of the geological feature of the target area according to the second geological feature and the third geological feature; and determining the first formation offset degree according to the change degree of the seismic time-depth relationship and the change degree of the geological feature.

[0009] In an exemplary embodiment, determining an injection state of injecting CO2 into the target area at a target time according to the first formation offset degree includes: determining a first difference between the offset target formation and the original formation according to the first formation offset degree, where the original formation is used to indicate the formation of the target area when CO2 has not been injected into the target object; determining a magnitude relationship between the first difference and a preset threshold, and determining the injection state according to the magnitude relationship.

[0010] In an exemplary embodiment, determining the injection state according to the magnitude relationship includes: when the magnitude relationship indicates that the first difference is less than or equal to the preset threshold, determining the injection state as continuous injection, and calculating an injection amount of CO2 allowed to be injected into the target object according to a second difference between the preset threshold and the first difference; when the magnitude relationship indicates that the first difference is greater than the preset threshold, determining the injection state as stop injection.

[0011] According to another embodiment of the embodiments of the present application, there is also provided a determining device for the injection state, including: a first determining module, configured to determine a first seismic wave of a target area where the target object is located by using three-dimensional seismic technology when it is detected that CO2 is injected into the target object; a second determining module, configured to determine a first formation offset degree of the target area according to the first seismic wave; a third determining module, configured to determine an injection state of injecting the CO2 into the target area at a target moment according to the first formation offset degree, where the target moment is the next moment of the current moment, and the injection state includes: stopping injection and continuing injection.

[0012] According to another aspect of the embodiments of the present application, there is also provided a computer-readable storage medium, in which a computer program is stored, and the computer program is configured to execute the above method when running.

[0013] According to another aspect of the embodiments of the present application, there is also provided an electronic device, including a memory, a processor, and a computer program stored on the memory and executable on the processor, where the above processor executes the above method through the computer program.

[0014] According to another aspect of the embodiments of the present application, there is also provided a computer program product, including a computer program, where the above computer program is executed by the processor to execute the above method.

[0015] In the embodiments of the present application, when it is detected that CO2 is injected into the target object, a first seismic wave of the target area where the target object is located is determined by using three-dimensional seismic technology, a first formation offset degree of the target area is determined according to the first seismic wave, and an injection state of CO2 at the next moment of the current moment is determined according to the first offset degree, that is, it is determined whether to stop injecting or continue injecting CO2 at the next moment of the current moment according to the first offset degree. That is to say, when it is detected that CO2 is injected into the target object, the present application determines a first seismic wave of the target area where the target object is located by using three-dimensional seismic technology. Compared with the method for determining seismic waves in the related art, the seismic wave determined by the method for determining seismic waves by using three-dimensional seismic technology is more accurate. The first seismic offset degree determined by the more accurate first seismic wave is also more accurate, and then the injection state of CO2 at the next moment of the current moment is determined. Through the embodiments of the present application, the injection state of CO2 at the next moment can be accurately judged. That is to say, the moment of stopping injecting CO2 can be accurately judged, and the problem of CO2 leakage caused by the inability to accurately judge the formation offset degree in the related art and thus the inability to accurately determine the moment of stopping injecting CO2 is solved. Furthermore, the risk of CO2 leakage can be detected in time, and the safety of the target area is guaranteed. Description of the Drawings

[0016] The accompanying drawings described herein are used to provide a further understanding of the present application and form a part of the present application. The schematic embodiments of the present application and their descriptions are used to explain the present application and do not constitute an improper limitation of the present application. In the drawings:

[0017] Figure 1 is a hardware structure block diagram of a computer terminal for a method of determining an injection state according to an embodiment of the present application;

[0018] Figure 2 is a flowchart of a method for determining an injection state according to an embodiment of the present application;

[0019] Figure 3 is a structure block diagram of a device for determining an injection state according to an embodiment of the present application. Detailed implementation manners

[0020] In order to enable those skilled in the art of the present technology to better understand the solutions of the present application, the technical solutions in the embodiments of the present application will be clearly and completely described below in conjunction with the accompanying drawings in the embodiments of the present application. Obviously, the described embodiments are only a part of the embodiments of the present application, rather than all the embodiments. Based on the embodiments in the present application, all other embodiments obtained by those of ordinary skill in the art without making creative efforts shall fall within the protection scope of the present application.

[0021] It should be noted that the terms "first", "second", etc. in the specification and claims of the present application and the above accompanying drawings are used to distinguish similar objects and do not necessarily need to describe a specific order or sequence. It should be understood that such data used may be interchanged under appropriate circumstances 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 variations thereof are intended to cover non-exclusive inclusion. For example, a process, method, system, product, or device that includes a series of steps or units does not necessarily need to be limited to those steps or units clearly listed, but may include other steps or units not clearly listed or inherent to these processes, methods, products, or devices; "a plurality" means two or more.

[0022] The method embodiments provided in the embodiments of the present application can be executed on a computer terminal or a similar computing device or a cloud platform or an independent physical server or a software platform, where the above software platform runs through one or more servers. Taking running on a computer terminal as an example, Figure 1 is a hardware structure block diagram of a computer terminal for a method of determining an injection state according to an embodiment of the present application. As Figure 1 shown, the computer terminal may include one or more ( Figure 1Only one processor 102 and a memory 104 for storing data are shown. In one exemplary embodiment, the computer terminal may further include a transmission device 106 for communication functions and an input / output device 108. Among them, the processor 102 may include, but is not limited to, a processing device such as a microprocessor MCU or a programmable logic device FPGA. Those of ordinary skill in the art can understand that Figure 1 The structure shown is only illustrative and does not limit the structure of the above computer terminal. For example, the computer terminal may further include more or fewer components than those Figure 1 shown in, or have the same functions as those Figure 1 shown or different configurations with more functions than those Figure 1 shown.

[0023] The memory 104 can be used to store computer programs. For example, software programs and modules of application software, such as the computer program corresponding to the method in the embodiments of the present application. The processor 102 executes various functional applications and data processing by running the computer program stored in the memory 104, that is, implements the above method. 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 memories, or other non-volatile solid-state memories. In some instances, the memory 104 may further include a memory remotely disposed relative to the processor 102, and these remote memories can be connected to the computer terminal through a network. Examples of the above network include, but are not limited to, the Internet, an enterprise intranet, a local area network, a mobile communication network, and combinations thereof.

[0024] The transmission device 106 is used to receive or send data via a network. Specific examples of the above network may include a wireless network provided by a communication provider of the computer terminal. In one instance, the transmission device 106 includes a network adapter (Network Interface Controller, abbreviated as NIC), which can be connected to other network devices through a base station and thus can communicate with the Internet. In one instance, the transmission device 106 may be a radio frequency (Radio Frequency, abbreviated as RF) module, which is used to communicate with the Internet wirelessly.

[0025] In this embodiment, a method for determining an injection state is provided, which is applied to the above computer terminal. Figure 2 is a flowchart of the method for determining the injection state according to the embodiments of the present application. The process includes the following steps:

[0026] Step S202, when it is detected that CO2 is injected into the target object, determine the first seismic wave of the target area where the target object is located by three-dimensional seismic technology;

[0027] Among them, the target object can be: a wellbore; the target area can be: the area where the wellbore is located.

[0028] Step S204: Determine the first formation offset degree of the target area according to the first seismic wave.

[0029] Step S206: Determine the injection state of injecting the CO2 into the target area at the target moment according to the first formation offset degree, where the target moment is the next moment of the current moment, and the injection state includes: stop injection, continue injection.

[0030] In the embodiment of the present application, when it is detected that CO2 is injected into the target object, the first seismic wave of the target area where the target object is located is determined by three-dimensional seismic technology. The first formation offset degree of the target area is determined according to the first seismic wave, and the injection state of CO2 at the next moment of the current moment is determined according to the first offset degree, that is, it is determined whether to stop injecting or continue injecting CO2 at the next moment of the current moment according to the first offset degree. That is to say, when it is detected that CO2 is injected into the target object, the first seismic wave of the target area where the target object is located is determined by three-dimensional seismic technology in the present application. Compared with the method for determining the seismic wave in the related technology, the seismic wave determined by the method for determining the seismic wave by three-dimensional seismic technology is more accurate. The first seismic offset degree determined by the more accurate first seismic wave is also more accurate, and then the injection state of CO2 at the next moment of the current moment is determined. Through the embodiment of the present application, the injection state of CO2 at the next moment can be accurately judged, that is to say, the moment of stopping injecting CO2 can be accurately judged, solving the problem of CO2 leakage caused by the inability to accurately judge the formation offset degree in the related technology and thus the inability to accurately determine the moment of stopping injecting CO2, and then the risk of CO2 leakage can be detected in time to ensure the safety of the target area.

[0031] Optionally, before determining the seismic wave of the target area where the target object is located by three-dimensional seismic technology in the above step S202, the method further includes: determining the position information corresponding to the target object, where the position information includes at least one of the following: the first geological feature corresponding to the target object, the provincial boundary situation corresponding to the target object; determining the deployment boundary of the three-dimensional seismic technology according to the position information; determining the target area according to the deployment boundary.

[0032] As can be seen from the above technical solutions, the deployment boundary of the 3D seismic technology can be determined by determining the position information corresponding to the target object, and then the target area corresponding to the 3D seismic technology can be determined. Specifically: The position information where the target object is located can be determined. Through the position information, the province where the target object is located can be determined, and then the provincial boundary situation corresponding to the target object can be determined. Through the provincial boundary situation, the deployment boundary and deployment direction corresponding to the 3D seismic technology can be determined, and then the target area can be determined. For example: If the structural trend of the target position is nearly north-south, then the deployment direction of the 3D seismic technology is nearly north-south.

[0033] Optionally, before determining the seismic wave of the target area where the target object is located by the 3D seismic technology in the above step S202, the method further includes: when it is detected that CO2 has not been injected into the target object, determining the second seismic wave of the target area by the 3D seismic technology; determining the first seismic time-depth relationship of the target area and the second geological characteristics of the target area according to the second seismic wave; and determining the second formation offset degree of the target area according to the first seismic time-depth relationship and the second geological characteristics.

[0034] It can be understood that before determining the seismic wave of the target object by the 3D seismic technology, it is also necessary to determine the second formation offset degree of the target area when CO2 has not been injected into the target area, and use the second formation offset degree as basic data. Specifically: determining the second seismic wave of the target area by the 3D seismic technology, and then determining the first seismic time-depth relationship of the target area and the second geological characteristics through the second seismic wave, and the second formation offset degree can be determined through the first seismic time-depth relationship and the second geological characteristics.

[0035] Among them, determining the first formation offset degree of the target area according to the first seismic wave includes: determining the second seismic time-depth relationship of the target area and the third geological characteristics of the target area according to the first seismic wave; determining the change degree of the seismic time-depth relationship of the target area according to the first seismic time-depth relationship and the second seismic time-depth relationship; and determining the change degree of the geological characteristics of the target area according to the second geological characteristics and the third geological characteristics; determining the first formation offset degree according to the change degree of the seismic time-depth relationship and the change degree of the geological characteristics.

[0036] It can be understood that the change degree of the seismic time-depth relationship of the target area can be determined according to the first seismic time-depth relationship of the target area without CO2 injection and the second seismic time-depth relationship of the target area with CO2 injection, and the change degree of the geological characteristics of the target area can be determined according to the second geological characteristics of the target area without CO2 injection and the third geological characteristics of the target area with CO2 injection. Then, the first formation offset degree is determined through the change degree of the seismic time-depth relationship and the change degree of the geological characteristics.

[0037] Optionally, determining the injection state of injecting the CO2 into the target area at the target moment according to the first formation offset degree in step S206 above includes: determining a first difference between the offset target formation and the original formation according to the first formation offset degree, where the original formation is used to indicate the formation of the target area in the case of not injecting the CO2 into the target object; determining the magnitude relationship between the first difference and a preset threshold, and determining the injection state according to the magnitude relationship.

[0038] Wherein, determining the injection state according to the magnitude relationship includes: when the magnitude relationship indicates that the first difference is less than or equal to the preset threshold, determining the injection state as continuous injection, and calculating the injection amount of the CO2 allowed to be injected into the target object according to a second difference between the preset threshold and the first difference; when the magnitude relationship indicates that the first difference is greater than the preset threshold, determining the injection state as stop injection.

[0039] It can be understood that the first difference between the offset formation and the original formation can be determined according to the first offset degree. When the first difference is less than or equal to the preset threshold, it is determined that the CO2 can be continuously injected, and the injection amount of the CO2 that can be injected into the target object can be determined according to the second difference between the preset threshold and the first difference. When the first difference is greater than the preset threshold, the injection of the CO2 into the target object is stopped.

[0040] To better understand the process of the above method for determining the injection state, the following further describes the method for determining the injection state in combination with optional embodiments, but it is not used to limit the technical solutions of the embodiments of the present application.

[0041] An optional embodiment of the present application provides a method for adjusting the injection amount of CO2. Among them, the microseismic monitoring technology (i.e., the three-dimensional seismic technology of the present application) can analyze the formation response of CO2 injection and identify the activation of natural fractures. The original recorded data and spectrum comparison diagrams of different periods of time-lapse vertical seismic profiling (Vertical Seismic Profiling, abbreviated as VSP) can be collected. Based on the changes in physical properties such as VSP velocity in different periods, as well as the trends, amplitudes, frequencies, wave impedances and other attributes of imaging data in different horizons, the migration direction and range of the CO2 plume are quantitatively interpreted, which is consistent with the actual gas injection volume law. The formation response monitoring technology can be combined with the seismic monitoring technology. The formation response monitoring technology is the address environmental disturbance, mainly including ground deformation (uplift or subsidence), etc. The underground migration of CO2 is monitored by VSP. A VSP monitoring is implemented once before injecting CO2 as the background value; during the injection process, a VSP monitoring can be carried out every once in a while (for example: every three years). Specifically:

[0042] (1) Preparation work: 3D seismic deployment principle:

[0043] 1) It can clarify the spatial distribution and fault characteristics of the Zhifang Formation to Shihezi sand bodies in the area where the wells are to be drilled, and evaluate the properties of reservoir-cap rock combinations.

[0044] 2) Determine the coverage range of the 3D exploration boundary (i.e., the deployment boundary of this application).

[0045] 3) In the range covered by 3D exploration, the structural strike is nearly north-south. Considering the provincial boundary situation, the 3D deployment direction is also nearly north-south.

[0046] 4) Regularly deploy the 3D full-coverage area, and use the variable acquisition processing method when collecting data.

[0047] (2) The first-phase monitoring, obtaining basic data before gas injection:

[0048] 1) Obtain the seismic time-depth relationship (i.e., the first seismic time-depth relationship of this application), amplitude attenuation law, formation velocity, and absorption attenuation parameter;

[0049] 2) Calibrate the positions and characteristics of the main horizons of the seismic data (i.e., the second geological characteristics of this application);

[0050] 3) Predict the formation distribution beside the wells, fault development and other structural conditions.

[0051] (3) The second-phase and subsequent monitoring, CO2 expansion front and fault development:

[0052] 1) Obtain the seismic time-depth relationship (i.e., the second seismic time-depth relationship of this application), amplitude attenuation law, formation velocity, and the change of absorption attenuation parameter Q;

[0053] 2) Analyze the changes in the cap rock and main reservoir distribution, fault development and other wellbore geological integrity after CO2 injection;

[0054] 3) Compare and analyze with the previous results to predict the changes in the CO2 migration range and direction of the main reservoir.

[0055] After injecting CO2, the formation will shift more or less. At this time, through the technical solutions of the above optional embodiments, the shift range of the formation is determined by the seismic waveform, and the difference between the shift range and the original formation (i.e., the first difference of this application) is determined. When the difference exceeds the second preset threshold, it is determined whether the difference is less than the first preset threshold. When it is less than the first preset threshold, it means that CO2 can continue to be injected, but the amount of CO2 to be injected needs to be calculated. And when it is greater than the first preset threshold, stop injecting CO2.

[0056] Through the description of the above embodiments, those skilled in the art can clearly understand that the method according to the above embodiments can be implemented by means of software plus a necessary general hardware platform. Of course, it can also be implemented by hardware, but in many cases, the former is a better implementation method. Based on such an understanding, the technical solution of the present application, in essence, or the part that contributes to the prior art can be embodied in the form of a software product. The computer software product is stored in a storage medium (such as ROM / RAM, magnetic disk, optical disk) and includes several instructions for causing a terminal device (which can be a mobile phone, computer, server, or network device, etc.) to execute the methods of the various embodiments of the present application.

[0057] The embodiment of the present application also provides a structural block diagram of a device for determining the injection state. Figure 3 It is a structural block diagram of the device for determining the injection state according to the embodiment of the present application; as Figure 3 shown, it includes:

[0058] The first determination module 32 is configured to, when detecting that CO2 is injected into the target object, determine the first seismic wave of the target area where the target object is located through three-dimensional seismic technology;

[0059] The second determination module 34 is configured to determine the first formation offset degree of the target area according to the first seismic wave;

[0060] The third determination module 36 is configured to determine the injection state of injecting the CO2 into the target area at the target moment according to the first formation offset degree, where the target moment is the next moment of the current moment, and the injection state includes: stop injection, continue injection.

[0061] With the above device, when it is detected that CO2 is injected into the target object, the first seismic wave of the target area where the target object is located is determined by three-dimensional seismic technology. The first formation offset degree of the target area is determined based on the first seismic wave, and the CO2 injection state at the next moment of the current moment is determined based on the first offset degree, that is, it is determined whether to stop or continue injecting CO2 at the next moment of the current moment based on the first offset degree. That is to say, when it is detected that CO2 is injected into the target object, the present application determines the first seismic wave of the target area where the target object is located by three-dimensional seismic technology. Compared with the method of determining seismic waves in the related art, the seismic wave determined by the method of determining seismic waves by three-dimensional seismic technology is more accurate. The first seismic offset degree determined by the more accurate first seismic wave is also more accurate, and then the CO2 injection state at the next moment of the current moment is determined. Through the embodiments of the present application, the CO2 injection state at the next moment can be accurately judged, that is to say, the moment of stopping injecting CO2 can be accurately judged, solving the problem of CO2 leakage caused by the inability to accurately judge the formation offset degree in the related art and thus the inability to accurately determine the moment of stopping injecting CO2, and then the CO2 leakage risk can be timely detected to ensure the safety of the target area.

[0062] In an exemplary embodiment, the first determination module 32 is further configured to determine the position information corresponding to the target object, where the position information includes at least one of the following: the first geological feature corresponding to the target object, the provincial boundary situation corresponding to the target object; determine the deployment boundary of the three-dimensional seismic technology according to the position information; and determine the target area according to the deployment boundary.

[0063] In an exemplary embodiment, the first determination module 32 is further configured to, when it is detected that the CO2 is not injected into the target object, determine the second seismic wave of the target area by the three-dimensional seismic technology; determine the first seismic time-depth relationship of the target area and the second geological feature of the target area according to the second seismic wave; and determine the second formation offset degree of the target area according to the first seismic time-depth relationship and the second geological feature.

[0064] In an exemplary embodiment, the second determination module 34 is further configured to determine the second seismic time-depth relationship of the target area and the third geological feature of the target area according to the first seismic wave; determine the change degree of the seismic time-depth relationship of the target area according to the first seismic time-depth relationship and the second seismic time-depth relationship; and determine the change degree of the geological feature of the target area according to the second geological feature and the third geological feature; determine the first formation offset degree according to the change degree of the seismic time-depth relationship and the change degree of the geological feature.

[0065] In an exemplary embodiment, the third determination module 36 is further configured to determine a first difference between the offset target formation and the original formation according to the first formation offset degree, where the original formation is used to indicate the formation of the target area without injecting the CO2 into the target object; determine the magnitude relationship between the first difference and a preset threshold, and determine the injection state according to the magnitude relationship.

[0066] In an exemplary embodiment, the third determination module 36 is further configured to, when the magnitude relationship indicates that the first difference is less than or equal to the preset threshold, determine the injection state as continuous injection, and calculate an injection amount of the CO2 allowed to be injected into the target object according to a second difference between the preset threshold and the first difference; when the magnitude relationship indicates that the first difference is greater than the preset threshold, determine the injection state as stop injection.

[0067] An embodiment of the present application further provides a storage medium, which includes a stored program. When the above program runs, it executes the method of any one of the above.

[0068] Optionally, in this embodiment, the above storage medium may be set to store program codes for executing the following steps:

[0069] S1. When it is detected that CO2 is injected into a target object, determine a first seismic wave of a target area where the target object is located by using three-dimensional seismic technology;

[0070] S2. Determine a first formation offset degree of the target area according to the first seismic wave;

[0071] S3. Determine an injection state of injecting the CO2 into the target area at a target moment according to the first formation offset degree, where the target moment is the next moment of the current moment, and the injection state includes: stop injection and continuous injection.

[0072] An embodiment of the present application further provides an electronic device, including a memory and a processor. 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.

[0073] Optionally, the above electronic device may further include a transmission device and an input / output device, where the transmission device is connected to the above processor, and the input / output device is connected to the above processor.

[0074] Optionally, in this embodiment, the above processor may be configured to execute the following steps through a computer program:

[0075] S1. When it is detected that CO2 is injected into the target object, determine the first seismic wave of the target area where the target object is located by using three-dimensional seismic technology;

[0076] S2. Determine the first formation offset degree of the target area according to the first seismic wave;

[0077] S3. Determine the injection state of injecting the CO2 into the target area at the target time according to the first formation offset degree, where the target time is the next moment of the current moment, and the injection state includes: stopping injection and continuing injection.

[0078] An embodiment of the present application further provides a computer program product, including a computer program, and the computer program is executed by a processor to perform the steps in any one of the above method embodiments.

[0079] Optionally, in this embodiment, the above computer program product can be executed by a processor to perform the following steps:

[0080] S1. When it is detected that CO2 is injected into the target object, determine the first seismic wave of the target area where the target object is located by using three-dimensional seismic technology;

[0081] S2. Determine the first formation offset degree of the target area according to the first seismic wave;

[0082] S3. Determine the injection state of injecting the CO2 into the target area at the target time according to the first formation offset degree, where the target time is the next moment of the current moment, and the injection state includes: stopping injection and continuing injection.

[0083] Optionally, in this embodiment, the above storage medium may include but is not limited to: USB flash drive, read-only memory (ROM for short), random access memory (RAM for short), mobile hard disk, magnetic disk or optical disc and other various media that can store program codes.

[0084] Optionally, the specific examples in this embodiment may refer to the examples described in the above embodiments and optional implementation manners, and will not be elaborated herein.

[0085] Obviously, those skilled in the art should understand that the various modules or steps of the present application described above can be implemented by a general-purpose computing device. They can be concentrated on a single computing device or distributed over a network composed of multiple computing devices. Optionally, they can be implemented by program codes executable by the computing device. Thus, 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 sequence different from that here, or they can be separately fabricated into individual integrated circuit modules, or multiple modules or steps among them can be fabricated 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.

[0086] The above are only the preferred embodiments of the present application and are not used to limit the present application. For those skilled in the art, the present application can have various changes and modifications. Any modification, equivalent replacement, improvement, etc. made within the principle of the present application shall be included within the protection scope of the present application.

Claims

1. A method for determining an injection state, characterized in that: include: In the case where injection of CO2 into the target object is detected, determining a first seismic wave of a target area where the target object is located by three-dimensional seismic technology; determining a first stratum displacement degree of the target area according to the first seismic wave; The injection state of injecting the CO2 into the target area at a target time is determined according to the first formation deviation degree, wherein the target time is a moment next to the current moment, and the injection state includes: stop injection and continue injection.

2. The method for determining the injection state according to claim 1, characterized in that: Before determining the seismic waves of the target area where the target object is located by three-dimensional seismic technology, the method further includes: Determine location information corresponding to the target object, wherein the location information includes at least one of the following: a first geological feature corresponding to the target object, and a provincial boundary corresponding to the target object; determining a deployment boundary of the three-dimensional seismic technology according to the location information; The target area is determined according to the deployment boundary.

3. The method for determining the injection state according to claim 1, characterized in that: Before determining the seismic waves of the target area where the target object is located by three-dimensional seismic technology, the method further includes: In the case where it is detected that the CO2 is not injected into the target object, determining a second seismic wave of the target area by using the three-dimensional seismic technology; Determining a first seismic time-depth relationship of the target area and a second geological feature of the target area according to the second seismic wave; A second stratum displacement degree of the target area is determined according to the first seismic time-depth relationship and the second geological feature.

4. The method for determining the injection state according to claim 3, characterized in that: Determining a first stratum displacement degree of the target area according to the first seismic wave includes: Determining a second seismic time-depth relationship of the target area and a third geological feature of the target area according to the first seismic wave; Determining the degree of change of the earthquake time-depth relationship of the target area according to the first earthquake time-depth relationship and the second earthquake time-depth relationship; and Determining the degree of change of the geological characteristics of the target area according to the second geological characteristics and the third geological characteristics; The first stratum displacement degree is determined according to the degree of change of the earthquake time-depth relationship and the degree of change of the geological characteristics.

5. The method for determining the injection state according to claim 1, characterized in that: Determining the injection state of injecting the CO2 into the target area at a target time according to the first formation deviation degree includes: Determining a first difference between the target stratum after the shift and the original stratum according to the first stratum shift degree, wherein the original stratum is used to indicate the stratum of the target area when the CO2 is not injected into the target object; The magnitude relationship between the first difference and a preset threshold is determined, and the injection state is determined according to the magnitude relationship.

6. The method for determining the injection state according to claim 5, characterized in that: Determining the injection state according to the size relationship includes: When the size relationship indicates that the first difference is less than or equal to the preset threshold, the injection state is determined to be continued injection, and the injection amount of the CO2 allowed to be injected into the target object is calculated based on the second difference between the preset threshold and the first difference; when the size relationship indicates that the first difference is greater than the preset threshold, the injection state is determined to be stopped injection.

7. A device for determining an injection state, characterized in that: include: A first determination module is used to determine a first seismic wave of a target area where the target object is located by using a three-dimensional seismic technology when it is detected that CO2 is injected into the target object; A second determination module, configured to determine a first stratum displacement degree of the target area according to the first seismic wave; The third determination module is used to determine the injection state of injecting the CO2 into the target area at a target time according to the first formation displacement degree, wherein the target time is the next moment of the current moment, and the injection state includes: stop injection and continue injection.

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

9. 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 6 through the computer program.

10. A computer program product, comprising a computer program, characterized in that The computer program is used by a processor to execute the method described in any one of claims 1 to 6.

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