Design method of carbon sequestration injection well

Abstract

The invention discloses a carbon sequestration injection well design method which comprises the following steps: acquiring stratum data of a predicted injection position of carbon dioxide; determining a first length of a sleeve of a carbon dioxide injection well allowed to be deployed at the predicted injection position through the stratum data, and determining materials allowed to be adopted by the sleeve and an oil pipe of the injection well based on a preset cost; indicating a target object to deploy an injection well with the length and the material according to a preset requirement; and receiving test data obtained by testing the injection well after well completion, so as to obtain injection parameters capable of ensuring the safety of the injection well through the test data. By means of the method, the problem that in the related technology, due to the fact that the safety of the shaft of the carbon dioxide injection well is poor, carbon dioxide sealing fails is solved.

Description

Technical Field

[0001] This application relates to the field of carbon sequestration technology, and more specifically, to a carbon sequestration injection well design method. Background Technology

[0002] Among related technologies, CCS / CCUS is the ultimate means of carbon emission reduction.

[0003] In the CCS / CCUS project, there have been issues with CO2 sequestration failures due to poor wellbore safety. For example: 1) Wellbore leakage: Inconsistencies between the deployment length of the injection well and the formation data at the deployment location, or damage to the well tubing and cement sheath, can cause CO2 to leak back to the surface. 2) Pipeline or operational leakage: The injection equipment and pipelines handle large amounts of CO2, creating a potential risk of routine errors and leaks.

[0004] There is still no effective solution to the problem of carbon dioxide storage failure due to poor wellbore safety in carbon dioxide injection wells in related technologies. Summary of the Invention

[0005] This application provides a carbon sequestration injection well design method to at least solve the problem in the prior art where poor wellbore safety of carbon dioxide injection wells leads to carbon dioxide sequestration failure.

[0006] According to one embodiment of this application, a carbon sequestration injection well design method is provided, comprising: acquiring formation data of the expected injection location of carbon dioxide; determining, through the formation data, a first length of casing for the carbon dioxide injection well permitted to be deployed at the expected injection location, and determining, based on a preset cost, the permitted materials for the casing and tubing of the injection well; instructing a target object to deploy an injection well having the specified length and material according to preset requirements; and receiving test data obtained from testing the injection well after completion, so as to obtain injection parameters that can ensure the safety of the injection well through the test data.

[0007] In one exemplary embodiment, determining a first length of casing for an injection well allowing deployment of the carbon dioxide at the intended injection location using the formation data includes: determining a second length of surface casing using depth data of a freshwater layer or a mineral layer under development in the formation data; determining a third length of technical casing using depth data of a caprock above the injection reservoir in the formation data; and determining a fourth length of production casing using depth data of the injection reservoir in the formation data; the first length of casing is determined using the second length, the third length, and the fourth length, wherein the casing includes: the surface casing, the technical casing, and the production casing.

[0008] In one exemplary embodiment, determining the permissible materials for the casing and tubing of the injection well based on a preset cost includes: determining the expected injection cycle of carbon dioxide in the injection well; and determining the permissible materials for the casing and tubing of the injection well based on the expected injection cycle and the preset cost.

[0009] In one exemplary embodiment, instructing a target object to deploy an injection well having the length and the material according to preset requirements includes: determining the wellbore enlargement rate of the entire well section of the injection well using oil and gas well target section standards; instructing the target object to deploy an injection well having the length and the material according to preset integrity requirements and the wellbore enlargement rate, wherein the preset requirements include: the section standards and the preset integrity requirements.

[0010] In one exemplary embodiment, receiving test data obtained from testing the injection well after completion includes: if multi-layer injection is permitted in the injection well after completion, receiving production logging data for each segment corresponding to the multi-layer injection obtained from production logging of the injection well after completion, wherein the test data includes: the production logging data; and receiving pressure test data obtained from pressure testing of the injection well after completion, wherein the test data includes: the pressure test data.

[0011] In an exemplary embodiment, obtaining injection parameters that can ensure the safety of the injection well through the test data includes: analyzing the test data using oil and gas field engineering software to obtain analysis results, wherein the analysis results include: the gas intake profile corresponding to each layer of the production logging data; and obtaining injection parameters that can ensure the safety of the injection well through the analysis results.

[0012] According to another embodiment of this application, a carbon sequestration injection well design apparatus is also provided, comprising: an acquisition module for acquiring formation data of the expected injection location of carbon dioxide; a determination module for determining, based on the formation data, a first length of casing for the carbon dioxide injection well permitted to be deployed at the expected injection location, and determining, based on a preset cost, the permitted materials for the casing and tubing of the injection well; an instruction module for instructing a target object to deploy an injection well having the specified length and material according to preset requirements; and a receiving module for receiving test data obtained from testing the injection well after completion, so as to obtain injection parameters that can ensure the safety of the injection well through the test data.

[0013] According to another aspect of the embodiments of this application, a computer-readable storage medium is also provided, wherein a computer program is stored in the computer program, and the computer program is configured to execute the above-described method at runtime.

[0014] According to another aspect of the embodiments of this application, an electronic device is also provided, including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the above-described method through the computer program.

[0015] According to another aspect of the embodiments of this application, a computer program product is also provided, including a computer program that, when executed by a processor, implements the steps in any of the above method embodiments.

[0016] In this embodiment, formation data of the expected carbon dioxide injection location is acquired; a first length of casing for the carbon dioxide injection well at the expected injection location is determined using the formation data, and the permissible materials for the casing and tubing of the injection well are determined based on a preset cost; the target object is instructed to deploy an injection well with the specified length and material according to preset requirements; test data obtained from testing the completed injection well is received, and injection parameters that ensure the safety of the injection well are obtained through the test data. Through the above embodiment, the problem of carbon dioxide storage failure due to poor wellbore safety in the prior art is solved, thereby improving the success rate of carbon dioxide storage. Attached Figure Description

[0017] The accompanying drawings, which are included to provide a further understanding of this application and form part of this application, illustrate exemplary embodiments and are used to explain this application, but do not constitute an undue limitation of this application. In the drawings:

[0018] Figure 1 This is a hardware structure block diagram of a computer terminal for a carbon sequestration injection well design method according to an embodiment of this application;

[0019] Figure 2 This is a flowchart of a carbon sequestration injection well design method according to an embodiment of this application;

[0020] Figure 3 This is a schematic diagram of an injection well according to the carbon sequestration injection well design method according to an embodiment of this application;

[0021] Figure 4 This is a schematic diagram of another injection well according to the carbon sequestration injection well design method according to an embodiment of this application;

[0022] Figure 5This is a schematic diagram of multi-layer injection of the carbon sequestration injection well design method according to an embodiment of this application;

[0023] Figure 6 This is a structural block diagram of a carbon sequestration injection well design device according to an embodiment of this application. Detailed Implementation

[0024] To enable those skilled in the art to better understand the present application, the technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present application, and not all embodiments. Based on the embodiments in the present application, all other embodiments obtained by those of ordinary skill in the art without creative effort should fall within the scope of protection of the present application.

[0025] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings of this application are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of this application described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover non-exclusive inclusion. For example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus; "a plurality" means two or more.

[0026] The methods and embodiments provided in this application can be executed on a computer terminal or similar computing device, cloud platform, independent physical server, or software platform, wherein the aforementioned software platform runs through one or more servers. Taking running on a computer terminal as an example, Figure 1 This is a hardware structure block diagram of a computer terminal for a carbon sequestration injection well design method according to an embodiment of this application. (See diagram below.) Figure 1 As shown, a computer terminal may include one or more ( Figure 1 Only one processor 102 and a memory 104 for storing data are shown in the diagram. In an exemplary embodiment, the computer terminal may further include a transmission device 106 for communication functions and an input / output device 108. 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 skilled in the art will understand that... Figure 1 The structure shown is for illustrative purposes only and does not limit the structure of the computer terminal described above. For example, the computer terminal may also include components that are more complex than those described above. Figure 1The more or fewer components shown, or having the same Figure 1 Equivalent functions or ratios shown Figure 1 The functions shown have more different configurations.

[0027] The memory 104 can be used to store computer programs, such as application software programs and modules, like the computer program corresponding to the method in this embodiment. The processor 102 executes various functional applications and data processing by running the computer program stored in the memory 104, thus implementing the above-described method. The memory 104 may include high-speed random access memory and non-volatile memory, such as one or more magnetic storage devices, flash memory, or other non-volatile solid-state memory. In some instances, the memory 104 may further include memory remotely located relative to the processor 102, and these remote memories can be connected to a computer terminal via a network. Examples of such networks include, but are not limited to, the Internet, corporate intranets, local area networks, mobile communication networks, and combinations thereof.

[0028] The transmission device 106 is used to receive or send data via a network. Specific examples of the network described above may include a wireless network provided by a communication provider for the computer terminal. In one example, the transmission device 106 includes a Network Interface Controller (NIC), which can connect to other network devices via a base station to communicate with the Internet. In another example, the transmission device 106 may be a Radio Frequency (RF) module used for wireless communication with the Internet.

[0029] This embodiment provides a carbon sequestration injection well design method, which is applied to the aforementioned computer terminal. Figure 2 This is a flowchart of a carbon storage injection well design method according to an embodiment of this application, which includes the following steps:

[0030] Step S202: Obtain formation data for the expected injection location of carbon dioxide;

[0031] Optionally, formation data can be obtained through geological exploration, such as core drilling and well logging (e.g., resistivity logging, nuclear magnetic resonance logging, etc.), while laboratory analysis can be performed to determine the chemical properties of formation fluids. The collected formation data includes the depth, physical properties, and chemical properties of each layer (e.g., freshwater layers, mineral layers); the physical and chemical properties include porosity, permeability, temperature, pressure, mineral composition, and corrosive environment, providing a basis for subsequent wellbore design.

[0032] Step S204: Determine the first length of the casing of the carbon dioxide injection well that is allowed to be deployed at the expected injection location using the formation data, and determine the materials that are allowed to be used for the casing and tubing of the injection well based on a preset cost.

[0033] Step S206: Instruct the target object to deploy an injection well with the specified length and material according to preset requirements;

[0034] Step S208: Receive test data obtained from testing the injection well after completion, and obtain injection parameters that can ensure the safety of the injection well through the test data.

[0035] Through the above steps, formation data of the expected carbon dioxide injection location is obtained; the formation data is used to determine a first length of casing for the carbon dioxide injection well at the expected injection location, and the permissible materials for the casing and tubing of the injection well are determined based on a preset cost; the target object is instructed to deploy an injection well with the specified length and material according to preset requirements; test data obtained from testing the completed injection well is received, and injection parameters that can ensure the safety of the injection well are obtained through the test data. Through the above embodiments, the problem of carbon dioxide sequestration loss due to poor wellbore safety in carbon dioxide injection wells in the prior art is solved.

[0036] In an optional embodiment, determining a first length of casing for the carbon dioxide injection well permitted to be deployed at the intended injection location using the formation data includes: determining a second length of surface casing using depth data of a freshwater layer or a mineral layer under development in the formation data; determining a third length of technical casing using depth data of a caprock above the injection reservoir in the formation data; and determining a fourth length of production casing using depth data of the injection reservoir in the formation data; the first length of casing is determined using the second length, the third length, and the fourth length, wherein the casing includes: the surface casing, the technical casing, and the production casing.

[0037] In this embodiment, the length of the casing at different levels in the CCS injection well is primarily determined based on formation depth data from the formation data, thereby determining the first length of the entire casing string. Specifically, to protect groundwater and known mineral resources from pollution or damage, and to ensure that the surface portion of the wellbore can withstand surface activity and shallow environmental pressures, the insertion depth of the surface casing (i.e., the second length) can be determined based on the depth of the freshwater layer or the mineral-producing layer in the formation data. Typically, the surface casing is inserted below the freshwater layer to prevent any construction activities from affecting the freshwater supply, while also ensuring coverage of all mineral-producing layers under development to avoid interference.

[0038] Technical casing is designed to isolate and protect the caprock (non-target layer) above the injected reservoir, ensuring that the sealed carbon dioxide does not escape upwards, while also supporting the wellbore and preventing formation collapse. Therefore, for technical casing, the required depth (i.e., the third length) can be calculated based on the caprock depth in the formation data. Technical casing typically extends to a certain depth below the caprock to ensure sufficient sealing and structural stability. The choice of this depth also depends on factors such as formation characteristics, storage depth, and injection pressure.

[0039] The production casing is in direct contact with the reservoir. Its main function is to provide a stable channel for injection and storage operations, while also supporting the wellbore to prevent reservoir collapse or leakage. The running depth (i.e., fourth length) of the production casing can be determined based on the depth data of the target injection reservoir. The production casing typically extends to or slightly beyond the bottom of the injection reservoir to cover the entire storage area, taking into account potential additional functions (such as tailpipe suspension) and reserved bottomhole space.

[0040] Finally, calculate the stacked length of all casing layers (surface casing, technical casing, and production casing) to determine the first length. It's important to note that in actual operation, there may be overlaps between casings (such as with tailpipe suspension technology); this overlap must also be included in the total length to ensure sufficient overlapping sealing sections. Optionally, oilfield engineering software can be used to simulate the effects of cementing at different depths based on the second, third, and fourth lengths, allowing for fine-tuning of these lengths to determine the maximum surface and technical casing lengths reaching the storage layer.

[0041] In one exemplary embodiment, determining the permissible materials for the casing and tubing of the injection well based on a preset cost includes: determining the expected injection cycle of carbon dioxide in the injection well; and determining the permissible materials for the casing and tubing of the injection well based on the expected injection cycle and the preset cost.

[0042] The corrosion resistance, cost, and service life of different materials commonly used for casing and tubing in injection wells are as follows: 1) Carbon steel: Lower cost, but susceptible to carbon dioxide corrosion, unsuitable for long-term injection operations without protective measures. 2) Stainless steel: Excellent corrosion resistance, suitable for long-term injection, but significantly more expensive than carbon steel. 3) Special alloys: Alloy materials have better corrosion resistance and strength, but are also more expensive. 4) Corrosion inhibitors: Can be used in conjunction with other materials to extend the service life of low-cost materials such as carbon steel and reduce the corrosion rate.

[0043] Furthermore, material selection is based on preset costs and injection cycles. For short-term injections (e.g., injection cycles less than 10 years), lower-cost materials like carbon steel can be prioritized, along with corrosion inhibitors to control corrosion risk. For medium-term injections (e.g., injection cycles of 10-20 years), a balance between cost and durability is required. Medium-cost materials can be chosen, and corrosion inhibitors or periodic replacement methods can be considered. For long-term injections (e.g., injection cycles greater than 20 years), higher durability and corrosion resistance are required. High-cost materials such as stainless steel or special alloys can be selected, even with higher initial investment, as long-term maintenance costs and operational efficiency will be superior to other materials. For medium- and long-term injections, high-cost materials can be prioritized for production casing, tubing, etc., based on preset costs.

[0044] In one exemplary embodiment, instructing a target object to deploy an injection well having the length and the material according to preset requirements includes: determining the wellbore enlargement rate of the entire well section of the injection well using oil and gas well target section standards; instructing the target object to deploy an injection well having the length and the material according to preset integrity requirements and the wellbore enlargement rate, wherein the preset requirements include: the section standards and the preset integrity requirements.

[0045] It should be noted that the enlargement rate refers to the percentage by which the actual wellbore diameter exceeds the designed diameter during drilling. This is to ensure wellbore cleanliness and smooth casing installation later. For CCS / CCUS injection wells, due to their special characteristics, the enlargement rate needs to be controlled more strictly to meet cementing quality and production efficiency requirements. The enlargement rate for the target formation is determined according to relevant industry standards for oil and gas wells. This standard is usually stricter than for general drilling to ensure wellbore stability. In addition to the target formation, the enlargement rate for the entire well section should also be controlled within a reasonable range to ensure cementing quality and wellbore structural integrity.

[0046] Preset integrity requirements are specific indicators of the overall performance and safety of the injection well, including but not limited to: the sealing between the casing and the cement sheath to ensure there are no leakage channels; the material selection for each layer of casing, determined based on the carbon dioxide injection cycle and corrosion risk; cementing quality, requiring a continuous length of high-quality cemented sections and a proportion of qualified well sections to ensure long-term sealing capability; and the stability of the wellbore structure to prevent wellbore collapse and wellbore deformation.

[0047] This instructs the target object to deploy injection wells by: combining drilling parameters (such as drilling pressure and rotation speed), wellbore trajectory design, casing size and material selection, cementing scheme, etc., outputting a deployment plan, and sending it to the target object. The target object is then instructed to deploy injection wells according to the deployment plan.

[0048] Optionally, the deployment of the injection well typically includes: ensuring drilling parameters conform to the plan, real-time monitoring of wellbore conditions, and timely adjustments to drilling operations, such as using appropriate drilling fluids to control wellbore stability. Based on the design length and material selection in the deployment plan, the surface casing, technical casing, and production casing are run, ensuring proper overlap and a good seal with the previous casing. After casing running, cementing is performed to ensure the sealing and corrosion resistance of the cement stone. Subsequently, a pressure test is conducted to ensure the integrity of the wellbore structure; the pressure test pressure should be higher than the expected injection pressure. Wellhead equipment is installed, including tubing hangers, packers, and water distributors, ensuring the correct installation of wellhead sealing and control equipment. After completion, pressure testing and injection tests are performed to obtain test parameters.

[0049] In one exemplary embodiment, receiving test data obtained from testing the injection well after completion includes: if multi-layer injection is permitted in the injection well after completion, receiving production logging data for each segment corresponding to the multi-layer injection obtained from production logging of the injection well after completion, wherein the test data includes: the production logging data; and receiving pressure test data obtained from pressure testing of the injection well after completion, wherein the test data includes: the pressure test data.

[0050] Understandably, conducting tests and obtaining test data in the injection well after completion is an important step in ensuring wellbore safety, assessing injection efficiency, and adjusting injection parameters.

[0051] The received test data includes, but is not limited to: production logging data, including gas intake profiles of each segment under multi-layer injection conditions, i.e., the intake of carbon dioxide in different segments. The data will show the injection efficiency and possible flow characteristics of each segment. Pressure test data, including pressure test data for wellbore sealing after completion, is used to verify the sealing and stability of the wellbore structure under high pressure.

[0052] Furthermore, obtaining injection parameters that can ensure the safety of the injection well through the test data includes: analyzing the test data using oil and gas field engineering software to obtain analysis results, wherein the analysis results include: the gas intake profile corresponding to each layer of the production logging data; and obtaining injection parameters that can ensure the safety of the injection well through the analysis results.

[0053] Optionally, specialized oil and gas field engineering software, such as Petrel, Eclipse, or OpenWorks, can be used for in-depth analysis of the test data. This software can aid in understanding and interpreting complex downhole conditions, such as fluid flow and pressure distribution. For example, analyzing production logging data, particularly the gas intake profile, can determine the injection capacity, flow resistance, and potential leakage paths for each section. Analyzing pressure test data can assess the sealing and integrity of the wellbore structure and identify any potential pressure loss points.

[0054] Furthermore, based on the analysis results of the gas intake profile, the injection rate and pressure can be adjusted to ensure effective distribution of carbon dioxide in the target formation while avoiding overpressure or leakage. In the case of multi-layer injection, the injection scheme can be optimized according to the gas intake of each formation, such as allocating different injection volumes to different formations to achieve relatively uniform injection throughout the well. In addition, based on the corrosion rate of the formation and the wellbore condition, it can be determined whether the use of anti-corrosion additives (e.g., the frequency of additive addition) or the tubing material needs to be adjusted to extend the wellbore's service life.

[0055] To better understand the process of the above carbon storage injection well design method, the following description will be based on optional embodiments, but this is not intended to limit the technical solutions of the embodiments of this application.

[0056] An optional embodiment of this application provides a computer-based method for adjusting injection parameters of a CCS safe injection well, including:

[0057] Based on formation data at a predetermined injection location, the formation data is analyzed via a computer terminal to determine the length of the injection well. Specifically, the injection well needs to include a surface casing reaching the freshwater layer at the storage point, a technical casing reaching the caprock, and a production casing employing tailpipe suspension technology, such as... Figure 3 As shown. Injection wells also include: tubing, etc., such as Figure 4 As shown. The analysis process on the computer terminal will incorporate the structure of the injection well.

[0058] Specifically, regarding the wellbore structure of the injection well:

[0059] Wellbore structure design should consider the special requirements for storage safety: the surface casing should extend below the freshwater layer and the mineral-producing layer being developed. A technical casing should be present, extending to the caprock above the injected reservoir to ensure the integrity of the wellbore seal. For CCS injection wells, the production casing should be cemented using a tailpipe suspension followed by cementing to ensure a good cement sheath seal integrity in the overlapping casing sections. These special requirements will be considered by the computer terminal during well depth structure design.

[0060] Specifically, the casing and tubing design for injection wells includes:

[0061] Although pure CO2 does not corrode tubing and casing, tubing and casing still face a corrosive environment due to possible leaks in the threads. Using stainless steel can significantly reduce this corrosion, but it will lead to a substantial increase in cost.

[0062] Optionally, the production casing and tubing of CCS and CCUS injection wells should use gas-tight threads, and the tubing needs to undergo gas-tightness testing. The tubing of CCS and CCUS injection-production wells should preferably be made of materials resistant to carbon dioxide corrosion. For CCUS production wells, the casing from the packer up to the wellhead (50 meters in length) can employ a corrosion prevention strategy combining carbon steel and corrosion inhibitors, taking into account the degree of corrosion throughout its lifespan.

[0063] For pure CCS injection, if the injection cycle is long, the casing should preferably be made of stainless steel. If the material's corrosion resistance is insufficient, corrosion inhibitors should be injected into the annulus. Packers for the CCS and CCUS injection layers should preferably be made of materials resistant to carbon dioxide corrosion. Regardless of the material used for tubing and casing, corrosion monitoring devices should be used to monitor the potential corrosion level. The computer terminal will select the injection well material based on the carbon dioxide injection cycle and cost.

[0064] Specifically, the cement stone design for the injection well includes:

[0065] The seal integrity of the cement ring is critical for CCS / CCUS.

[0066] Cement stone should possess a certain degree of corrosion resistance. For CCUS, a tightly packed, corrosion-resistant cement slurry system can be used, with the addition of certain corrosion-resistant additives to create a tight packing effect. Reducing the permeability of the cement stone can significantly slow down the cement corrosion rate. Conventional cement is a brittle material, and changes in injection well pressure and temperature can cause defects in the cement sheath. CCS / CCUS injection well cement should be toughened to reduce the elastic modulus of the cement stone.

[0067] Among them, the control of wellbore quality and cementing quality of injection wells includes:

[0068] When deploying injection wells to the designated target area, the wellbore enlargement rate should be strictly controlled to ensure cementing quality. Except for the surface layer, the wellbore enlargement rate for the entire well section should be in accordance with the standards for the target formation of oil and gas wells, and scrambled wellbores should not be formed.

[0069] The cementing quality requirements are higher than those for conventional oil and gas wells. Referring to the integrity requirements of gas storage wells and high-temperature, high-efficiency wells, key cementing sections such as caprock sections, tailpipe overlapping sections, and interlayer sections between different layers should have a continuous high-quality cementing section of no less than 25m, and qualified sections should account for more than 70% of the total cementing sections.

[0070] Before reconnecting the casing, a negative pressure test should be performed. If a leakage path is found, a short-circuit cementing should be performed before reconnecting the casing to the surface normally. The pressure test after cementing should be carried out as soon as possible after the cementing pressure test, and the test pressure should not be less than 1.2 times the maximum injection pressure.

[0071] Furthermore, multi-layered injection wells can be used, such as... Figure 5 As shown, to improve the injection capacity of CCS: when the single-layer sealing capacity and injection capacity are limited, multi-layer mixed injection and multi-layer distributed injection can be considered when implementing CCS. Among them, the multi-layer unified injection completion method and injection are the simplest, but the sealing volume per unit sealing area is limited. Multi-layer distributed injection can divide the entire well section into several layers according to the differences in sand groups. The relatively uniform injection between multiple layers can be achieved through the distributed injection method, thereby improving the sealing capacity per unit area.

[0072] This includes testing and trial injection of injection wells. After completion, CCS injection wells should be tested. This serves two purposes: firstly, to unblock the reservoir through pumping and drainage; and secondly, to understand the formation's injection capacity parameters, providing fundamental data for rational injection allocation. Trial injection can be performed during testing to obtain injection parameters. Monitoring these parameters allows for optimization of injection allocation, achieving balanced injection. Production logging can be conducted during trial injection to measure the gas intake profile of each layer, thereby adjusting and optimizing injection allocation parameters. The test data obtained can be input into a computer terminal, and software analysis can be used to determine the optimal injection parameters for actual carbon dioxide injection into the injection well.

[0073] Through the above description of the embodiments, those skilled in the art can clearly understand that the methods according to the above embodiments can be implemented by means of software plus necessary general-purpose hardware platforms. Of course, they can also be implemented by hardware, but in many cases the former is a better implementation method. Based on this understanding, the technical solution of this application, in essence, or the part that contributes to the prior art, can be embodied in the form of a software product. This computer software product is stored in a storage medium (such as ROM / RAM, magnetic disk, optical disk) and includes several instructions to cause a terminal device (which may be a mobile phone, computer, server, or network device, etc.) to execute the methods of the various embodiments of this application.

[0074] This application also provides a structural block diagram of a carbon sequestration injection well design device. Figure 6 This is a structural block diagram of a carbon sequestration injection well design device according to an embodiment of this application; as shown... Figure 6 As shown, it includes:

[0075] Acquisition module 62 is used to acquire formation data of the expected injection location of carbon dioxide;

[0076] The determination module 64 is used to determine, through the formation data, a first length of casing for the carbon dioxide injection well that is allowed to be deployed at the expected injection location, and to determine, based on a preset cost, the materials that are allowed to be used for the casing and tubing of the injection well, respectively.

[0077] Instruction module 66 is used to instruct the target object to deploy an injection well with the specified length and material according to preset requirements;

[0078] The receiving module 68 is used to receive test data obtained from testing the injection well after completion, so as to obtain injection parameters that can ensure the safety of the injection well through the test data.

[0079] The aforementioned apparatus acquires formation data of the expected carbon dioxide injection location; determines, based on the formation data, a first length of casing for the carbon dioxide injection well at the expected injection location, and determines the permissible materials for the casing and tubing of the injection well based on a preset cost; instructs the target to deploy an injection well with the specified length and material according to preset requirements; and receives test data obtained from testing the completed injection well to obtain injection parameters that ensure the safety of the injection well. This embodiment solves the problem in the prior art where poor wellbore safety in carbon dioxide injection wells leads to carbon dioxide storage failure, thereby improving the success rate of carbon dioxide storage.

[0080] In an exemplary embodiment, the determining module 64 is further configured to: determine a second length of the surface casing using depth data of a freshwater layer or depth data of a mineral layer under development in the formation data; determine a third length of the technical casing using depth data of a caprock above the injected reservoir in the formation data; determine a fourth length of the production casing using depth data of the injected reservoir in the formation data; and determine a first length of the casing using the second length, the third length, and the fourth length, wherein the casing includes: the surface casing, the technical casing, and the production casing.

[0081] In an exemplary embodiment, the determining module 64 is further configured to: determine the expected injection cycle of carbon dioxide in the injection well; and determine the permissible materials for the casing and tubing of the injection well based on the expected injection cycle and the preset cost.

[0082] In an exemplary embodiment, the instruction module 66 is further configured to: determine the wellbore enlargement rate of the entire well section of the injection well through the target section standard of the oil and gas well; instruct the target object to deploy an injection well having the length and the material in accordance with the preset integrity requirements and the wellbore enlargement rate, wherein the preset requirements include: the section standard and the preset integrity requirements.

[0083] In an exemplary embodiment, the receiving module 68 is further configured to: receive production logging data for each segment corresponding to the multi-layer injection obtained by production logging of the injection well after completion, where multi-layer injection is permitted after completion, wherein the test data includes the production logging data; and receive pressure test data obtained by pressure testing of the injection well after completion, wherein the test data includes the pressure test data.

[0084] In an exemplary embodiment, the receiving module 68 is further configured to: analyze the test data using oil and gas field engineering software to obtain analysis results, wherein the analysis results include: the gas intake profile corresponding to each layer of the production logging data; and obtain injection parameters that can ensure the safety of the injection well through the analysis results.

[0085] Embodiments of this application also provide a storage medium including a stored program, wherein the program executes any of the methods described above when it is run.

[0086] Optionally, in this embodiment, the storage medium may be configured to store program code for performing the following steps:

[0087] S1, Obtain formation data for the expected injection location of carbon dioxide;

[0088] S2, using the formation data, determine the first length of the casing of the carbon dioxide injection well that is allowed to be deployed at the expected injection location, and determine the materials that are allowed to be used for the casing and tubing of the injection well based on a preset cost;

[0089] S3, instructing the target object to deploy an injection well with the specified length and material according to preset requirements;

[0090] S4, receive test data obtained from testing the injection well after completion, and obtain injection parameters that can ensure the safety of the injection well through the test data.

[0091] Embodiments of this application also provide an electronic device including a memory and a processor, wherein the memory stores a computer program and the processor is configured to run the computer program to perform the steps in any of the above method embodiments.

[0092] Optionally, 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.

[0093] Optionally, in this embodiment, the processor can be configured to perform the following steps via a computer program:

[0094] S1, Obtain formation data for the expected injection location of carbon dioxide;

[0095] S2, using the formation data, determine the first length of the casing of the carbon dioxide injection well that is allowed to be deployed at the expected injection location, and determine the materials that are allowed to be used for the casing and tubing of the injection well based on a preset cost;

[0096] S3, instructing the target object to deploy an injection well with the specified length and material according to preset requirements;

[0097] S4, receive test data obtained from testing the injection well after completion, and obtain injection parameters that can ensure the safety of the injection well through the test data.

[0098] Optionally, in this embodiment, the storage medium may include, but is not limited to, various media capable of storing program code, such as USB flash drives, read-only memory (ROM), random access memory (RAM), portable hard drives, magnetic disks, or optical disks.

[0099] Embodiments of this application also provide a computer program product, which includes a computer program that, when executed by a processor, implements the steps in any of the above method embodiments.

[0100] Embodiments of this application also provide another computer program product, including a non-volatile computer-readable storage medium storing a computer program that, when executed by a processor, implements the steps in any of the above method embodiments.

[0101] Embodiments of this application also provide a computer program that includes computer instructions stored in a computer-readable storage medium; a processor of a computer device reads the computer instructions from the computer-readable storage medium and executes the computer instructions, causing the computer device to perform the steps in any of the above method embodiments.

[0102] Optionally, specific examples in this embodiment can refer to the examples described in the above embodiments and optional implementations, and will not be repeated here.

[0103] Obviously, those skilled in the art should understand that the modules or steps of this application described above can be implemented using general-purpose computing devices. They can be centralized on a single computing device or distributed across a network of multiple computing devices. Optionally, they can be implemented using computer-executable program code, thereby storing them in a storage device for execution by a computing device. In some cases, the steps shown or described can be performed in a different order than those presented here, or they can be fabricated as separate integrated circuit modules, or multiple modules or steps can be fabricated as a single integrated circuit module. Thus, this application is not limited to any particular combination of hardware and software.

[0104] The above description is merely a preferred embodiment of this application and is not intended to limit this application. Various modifications and variations can be made to this application by those skilled in the art. Any modifications, equivalent substitutions, improvements, etc., made within the principles of this application should be included within the protection scope of this application.

Claims

1. A method for designing carbon sequestration injection wells, characterized in that, include: Obtain formation data for the expected carbon dioxide injection location; The formation data is used to determine the first length of the casing of the carbon dioxide injection well that is allowed to be deployed at the expected injection location, and the materials that are allowed to be used for the casing and tubing of the injection well are determined based on a preset cost. Instruct the target object to deploy an injection well with the specified length and material according to preset requirements; Receive test data obtained from testing the injection well after completion, and obtain injection parameters that can ensure the safety of the injection well through the test data.

2. The carbon sequestration injection well design method according to claim 1, characterized in that, Determining the first length of casing for the carbon dioxide injection well permitted to be deployed at the intended injection location using the formation data includes: The second length of the surface casing is determined using depth data of freshwater layers or depth data of mineral-bearing layers under development from the formation data; and, The third length of the technical casing is determined using the depth data of the caprock above the injected reservoir from the formation data; and, The fourth length of the production casing is determined using the depth data of the injected reservoir in the formation data; The first length of the sleeve is determined by the second length, the third length, and the fourth length, wherein the sleeve includes: the surface sleeve, the technical sleeve, and the production sleeve.

3. The carbon sequestration injection well design method according to claim 1, characterized in that, The permissible materials for the casing and tubing of the injection well are determined based on a preset cost, including: Determine the expected injection cycle of carbon dioxide for the injection well; The materials that can be used for the casing and tubing of the injection well are determined by the expected injection cycle and the preset cost.

4. The carbon sequestration injection well design method according to claim 1, characterized in that, Instructing the target object to deploy an injection well with the stated length and material according to preset requirements includes: The wellbore enlargement rate of the entire injection well section is determined by the target formation standard of the oil and gas well. The target object is instructed to deploy an injection well with the specified length and material in accordance with the preset integrity requirements and the specified well diameter enlargement rate, wherein the preset requirements include: the layer standard and the preset integrity requirements.

5. The carbon sequestration injection well design method according to claim 1, characterized in that, Receive test data obtained from testing the injection well after completion, including: If multi-stage injection is permitted in the injection well after completion, the production logging data corresponding to each stage of the multi-stage injection obtained by production logging of the injection well after completion is received, wherein the test data includes: the production logging data; Receive pressure test data obtained from pressure testing of the injection well after well completion, wherein the test data includes: the pressure test data.

6. The carbon sequestration injection well design method according to claim 5, characterized in that, The injection parameters that ensure the safety of the injection well are obtained from the test data, including: The test data is analyzed using oil and gas field engineering software to obtain analysis results, which include: the gas intake profiles corresponding to each layer of the production logging data; The analysis results are used to obtain injection parameters that can ensure the safety of the injection well.

7. A carbon sequestration injection well design device, characterized in that, include: The acquisition module is used to acquire formation data for the expected injection location of carbon dioxide; The determination module is used to determine, through the formation data, a first length of casing for the carbon dioxide injection well that is permitted to be deployed at the expected injection location, and to determine, based on a preset cost, the permitted materials for the casing and tubing of the injection well, respectively. An instruction module is used to instruct the target object to deploy an injection well with the specified length and material according to preset requirements; The receiving module is used to receive test data obtained from testing the injection well after completion, so as to obtain injection parameters that can ensure the safety of the injection well through the test data.

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

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

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

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