Carbon dioxide oil displacement and underground storage cooperative control method and system

Abstract

The invention provides a carbon dioxide oil displacement and underground storage cooperative control method and system, and belongs to the technical field of carbon dioxide oil displacement and underground storage. The method comprises the steps that oil reservoir basic data and initial state data of an oil reservoir geologic model are collected and subjected to standardization processing, and oil reservoir data are obtained; designing a self-adaptive well pattern layout, and constructing a multi-field coupling early warning system; a bidirectional linkage mechanism of injection-production optimization driving early warning adjustment and risk early warning driving well pattern regulation and control is combined; constructing a continuous sealing barrier for the target oil reservoir area by utilizing a directional isolation technology; a multi-field coupling early warning system is used for monitoring the long-acting sealing barrier, and a preset sealing guarantee system is formed. According to the method, re-drilling in the sealing stage is not needed, the sealing stability of the sealing area is improved, the risk disposal response time is shortened, the accurate positioning of the risk point is realized, the oil displacement efficiency attenuation rate is reduced, the recovery efficiency is improved, the sealing risk pre-judgment accuracy is improved, and the resource utilization rate is improved.

Description

Technical Field

[0001] This invention relates to the field of carbon dioxide flooding and underground storage technology, specifically to a method and system for the coordinated control of carbon dioxide flooding and underground storage. Background Technology

[0002] Carbon dioxide enhanced oil recovery (CED) and underground storage is a technology that combines the dual value of resource development and carbon emission reduction. Its core is to inject captured carbon dioxide into underground oil reservoirs, achieving a synergistic effect of "oil displacement and efficiency enhancement" and "permanent storage." After injection, carbon dioxide reduces crude oil viscosity, improves the oil-water mobility ratio, and dissolves and expands the crude oil, thus driving previously difficult-to-extract remaining oil towards the production well. After oil displacement, the unrecovered carbon dioxide is fixed by the reservoir's geological traps, rock pores, formation water dissolution, and mineral carbonization, remaining underground for a long period and preventing it from entering the atmosphere and contributing to the greenhouse effect.

[0003] In existing technologies, during carbon dioxide flooding and underground storage, the well network only serves oil production efficiency during the oil displacement phase. During the storage phase, isolation wells or monitoring wells need to be redeployed, leading to extended construction periods, increased costs, and poor compatibility between the storage barrier and the original well network. Risks such as carbon dioxide crossflow and storage leakage can only be passively alarmed, lacking a closed-loop warning-response system, resulting in delayed risk response and potential loss of oil displacement efficiency or environmental risks. Furthermore, there is a lack of adaptability to the entire life cycle of reservoir dynamics. Injection and production parameters, warning thresholds, and storage strategies are fixed and cannot be dynamically optimized according to the distribution of remaining oil in the reservoir and changes in formation stress, leading to a decline in oil displacement efficiency or storage stability in the later stages. Summary of the Invention

[0004] The purpose of this invention is to provide a method and system for the coordinated control of carbon dioxide flooding and underground storage, in order to solve the technical problems in the prior art, such as the need to redeploy isolation wells during the storage stage, poor compatibility with the original well network, delayed risk response leading to loss of oil displacement efficiency, and lack of full life cycle adaptability to reservoir dynamic changes.

[0005] To achieve the above objectives, this invention provides a method for coordinated control of carbon dioxide enhanced oil recovery and underground storage. The method includes: acquiring reservoir basic data from a reservoir geological model using geological exploration techniques; acquiring initial state data from sensors deployed in the target reservoir area and standardizing the data to obtain reservoir data; designing an adaptive well network layout based on the reservoir data and constructing a multi-field coupled early warning system to match well network functions with early warning monitoring; utilizing the adaptive well network layout and the multi-field coupled early warning system, combined with a two-way linkage mechanism of injection-production optimization-driven early warning adjustment and risk early warning-driven well network regulation, to achieve deep coordination between adaptive well network dynamic function switching and multi-field coupled early warning system monitoring; after determining that the oil recovery effect in the target reservoir area meets the standards, constructing a continuous sealing barrier for the target reservoir area using directional isolation technology; and monitoring the long-term sealing barrier using the multi-field coupled early warning system to form a pre-set storage guarantee system, achieving stable carbon dioxide storage.

[0006] Optionally, the design of the adaptive well network layout includes: classifying well types according to reservoir characteristics and development needs in the reservoir data; designing a spatial layout based on the remaining oil distribution data in the reservoir data; presetting key parameters according to potential crossflow channels in the reservoir data; using reservoir numerical simulation software to verify the well network effect under different injection and production scenarios, and generating an adaptive well network layout by combining well type classification, spatial layout and key parameters.

[0007] Optionally, the construction of the multi-field coupling early warning system includes: planning a three-dimensional monitoring architecture between wells and inside wells according to the adaptive well network layout; deploying distributed optical fibers between wells and installing corresponding sensors at preset locations inside wells; constructing multi-level data transmission links based on the data from the distributed optical fibers and sensors, and establishing a correlation mapping between monitoring data and well network locations to generate a multi-field coupling early warning system.

[0008] Optionally, the injection-production optimization-driven early warning adjustment includes: monitoring the oil displacement effect based on data collected by distributed optical fibers and combined with preset judgment criteria; when the oil displacement effect reaches the preset judgment criteria, the collaborative control system generates and executes a well function switching command; after the well function switching command is executed, the sensor acquisition frequency is increased to monitor the diffusion trend of carbon dioxide and dynamically optimize the early warning parameters of the multi-field coupling early warning system.

[0009] Optionally, the risk warning-driven well network regulation includes: analyzing data from distributed optical fibers and sensors; when abnormal pressure changes and a synchronous abnormal increase in carbon dioxide concentration are detected, it is determined to be a crossflow risk and a graded warning is triggered; based on the triggered graded warning, an emergency regulation command for the well network is generated and executed through a collaborative control system, and the warning information is pushed to the user for confirmation; after the user confirms the warning information, the preset isolation zone is temporarily sealed and reinforced.

[0010] Optionally, the method of constructing a continuous sealing barrier for the target reservoir area using directional isolation technology includes: delineating the boundary between the oil displacement zone and the storage zone by combining reservoir data, injection-production optimization data, and carbon dioxide distribution monitoring results through numerical simulation; injecting curable gel into the isolation zone through pre-designated sealing wells according to the delineated boundary to form a continuous sealing barrier; and using pre-designated sealing testing technology to detect the integrity of the continuous sealing barrier. If a leak is detected, curable gel is injected until the standard is met.

[0011] Optionally, the use of a multi-field coupling early warning system to monitor the long-term sealing barrier and form a preset storage guarantee system includes: using the multi-field coupling early warning system to collect multi-source data of the storage area at a preset frequency; conducting inspections of the storage monitoring wells, isolation zones and early warning equipment at a preset cycle; summarizing the monitoring data at a preset time period, and predicting the long-term storage stability of carbon dioxide through numerical simulation to generate a storage monitoring report.

[0012] Optionally, the collaborative control method further includes: utilizing the SCADA control system to integrate the data flow and command flow of the collaborative control system, performing closed-loop command execution through a dedicated linkage module, and iteratively optimizing the parameters of the collaborative control system based on the operating data of the SCADA control system.

[0013] Optionally, the method of utilizing the SCADA control system to integrate the data flow and command flow of the collaborative control system, and to perform closed-loop command execution through a dedicated linkage module, includes: deploying the SCADA control system to integrate the data flow and command flow of each link of the collaborative control system to achieve closed-loop management of data-command-execution-feedback; developing a dedicated linkage module for early warning and control to convert the monitoring data of the multi-field coupled early warning system into executable commands for well network control; setting hierarchical operation permissions, configuring data encryption and log recording functions to ensure that the operation of the SCADA control system is traceable and the data is secure and controllable.

[0014] On the other hand, the present invention also provides a coordinated control system for carbon dioxide enhanced oil recovery and underground storage. The coordinated control system includes a control module, which includes a memory, a processor, and a computer program stored in the memory and executable on the processor. The processor executes the computer program to implement the coordinated control method described in any of the above.

[0015] Through the above technical solutions, by designing an adaptive well network layout and directional isolation technology, it is possible to eliminate the need for re-drilling during the sealing phase, shorten the construction period compared to traditional technologies, reduce costs, improve the compatibility of the isolation zone with the original well network, enhance the integrity of the sealing barrier, and improve the sealing stability of the sealing area. By deploying a multi-field coupled early warning system and risk early warning-driven well network adjustment, the risk response time is shortened, the sealing leakage rate is reduced, and the risk point is accurately located. Through injection-production optimization-driven early warning and full-process data iterative optimization, the oil displacement efficiency decay rate is reduced, the recovery rate is improved, the long-term stability of the sealing area is enhanced, the accuracy of sealing risk prediction is improved, and the resource utilization rate is increased.

[0016] Other features and advantages of the present invention will be described in detail in the following detailed description section. Attached Figure Description

[0017] The accompanying drawings are provided to further illustrate embodiments of the present invention and form part of the specification. They are used together with the following detailed description to explain the embodiments of the present invention, but do not constitute a limitation thereof. In the drawings: Figure 1 This is a flowchart illustrating the synergistic control method of carbon dioxide enhanced oil recovery and underground storage according to the present invention. Figure 1 ; Figure 2 This is a schematic diagram of the process for designing an adaptive well network layout in this invention; Figure 3 This is a schematic diagram of the process for constructing a multi-field coupled early warning system in this invention; Figure 4 This is a schematic diagram of the injection-progression optimization-driven early warning adjustment process in this invention; Figure 5 This is a schematic diagram of the process of risk warning-driven well network regulation in this invention; Figure 6 This is a schematic diagram of the process for constructing a continuous sealing barrier for a target reservoir area in this invention; Figure 7 This is a schematic diagram of the process for forming the preset sealing and protection system in this invention; Figure 8 This is a flowchart illustrating the closed-loop execution of instructions in this invention; Figure 9 This is a flowchart illustrating the synergistic control method of carbon dioxide enhanced oil recovery and underground storage according to the present invention. Figure 2 . Detailed Implementation

[0018] The specific embodiments of the present invention will be described in detail below with reference to the accompanying drawings. It should be understood that the specific embodiments described herein are for illustration and explanation only and are not intended to limit the scope of the present invention.

[0019] It should be noted that the acquisition, transmission, storage, use, and processing of data in the technical solution of this application all comply with the relevant provisions of national laws and regulations. In the embodiments of this application, certain existing industry solutions such as software, components, and models may be mentioned. These should be considered exemplary, intended only to illustrate the feasibility of implementing the technical solution of this application, and do not imply that the applicant has already used or necessarily used such solutions.

[0020] Please refer to Figure 1 This invention provides a method for the coordinated control of carbon dioxide enhanced oil recovery and underground storage, which may include: Step S100: Using geological exploration technology, collect basic reservoir data from the reservoir geological model. Based on sensors deployed in the target reservoir area, collect initial state data and perform standardization processing to obtain reservoir data.

[0021] Combination Figure 9 In this embodiment of the invention, when collecting basic reservoir data, the overall structure of the reservoir can be detected by three-dimensional seismic exploration technology to clarify the distribution of geological interfaces such as faults and interlayers. Well logging technology (e.g., sonic logging, density logging) can be used to obtain data on the thickness, lithology, and porosity of each layer, with a focus on identifying the thickness and integrity of the caprock. Core sampling can be carried out at key well locations, and data on rock mineral composition, permeability, and pore structure can be obtained through laboratory core analysis. In order to meet the core needs of oil displacement and storage, the location and development scale data of the remaining oil distribution characteristics (e.g., through closed coring, water-flooded layer logging, etc.) and potential channeling channels (e.g., faults, high-permeability interlayers) can be collected to clarify the spatial attributes and resource distribution patterns of the reservoir.

[0022] In this embodiment of the invention, when collecting initial state data, temporary monitoring points can be set up in the central area of ​​the reservoir, near faults, around expected injection and production well locations, and at key caprock locations based on reservoir baseline data to ensure coverage of the core reservoir area and risk areas. Temporary pressure sensors, temperature sensors, CO2 concentration sensors, and crude oil sampling devices can be deployed at the temporary monitoring points. The sensors need to undergo high-temperature and high-pressure environment adaptability tests in advance to ensure stable operation under reservoir conditions. A combination of continuous monitoring and intermittent sampling can be used to collect initial reservoir pressure and temperature baseline data. A stable baseline can be obtained by continuous monitoring for 7-15 days. Crude oil viscosity, density, wax content, and other physical properties can be obtained through crude oil sampling analysis. The collected data should be recorded in real time, and the collection time, location, and environmental conditions (e.g., well depth and formation temperature at the time of sampling) should be marked to avoid data confusion.

[0023] In this embodiment of the invention, during standardization processing, abnormal data during the acquisition process can be removed, and missing data can be supplemented using interpolation to ensure data integrity; data format and units are unified (for example, pressure unit is unified to MPa, temperature unit is unified to ℃), data coding rules are established, and data is categorized and coded according to "geological data-state data-physical property data"; all processed data are entered into the reservoir data management platform to construct a "reservoir spatial attributes-initial state-physical property parameters" related database.

[0024] Step S200: Based on reservoir data, design an adaptive well network layout and construct a multi-field coupled early warning system to match the well network function with early warning monitoring.

[0025] Please refer to Figure 2 In this embodiment of the invention, designing an adaptive well pattern layout may include: Step S210: Classify well types based on reservoir characteristics and development needs in the reservoir data.

[0026] In a preferred embodiment of the present invention, well types can be divided into three categories: main injection wells (e.g., those that undertake the task of stable CO2 injection and have fixed functions), adjustable injection / production wells (e.g., those that can flexibly switch between injection / production functions during the oil displacement period to adapt to dynamic changes in remaining oil), and monitoring / storage wells (e.g., those that monitor risks during the oil displacement period and switch to storage monitoring and emergency injection wells during the storage period). The pressure tolerance capacity, pipe diameter specifications, and other technical parameters of each type of well are also specified.

[0027] Step S220: Design the spatial layout based on the remaining oil distribution data in the reservoir data.

[0028] In a preferred embodiment of the present invention, adjustable injection or production wells can be deployed in densely packed areas of remaining oil based on the remaining oil distribution data to ensure that the distance between wells meets the requirements for effective CO2 sweep. Monitoring or storage wells are deployed in a “surrounding” layout around weak caprock areas and potential crossflow channels to achieve full coverage of risk points. Main injection wells are deployed in the reservoir center or in locations with convenient CO2 transport, and the surrounding adjustable wells and monitoring wells are connected by a diamond layout to ensure uniform CO2 diffusion.

[0029] Step S230: Based on the potential crossflow channels in the reservoir data, preset key parameters.

[0030] In a preferred embodiment of the present invention, for potential crossflow channels, the directional perforation angle, depth and density of adjustable wells and main injection wells can be preset by numerical simulation based on their direction and angle to ensure that the perforation direction avoids high-risk areas and accurately points to the remaining oil area; then, based on the simulation results of the crossflow channel diffusion range, the location, width and well location for plugging are preset (for example, monitoring or sealing wells are selected as plugging injection wells).

[0031] Step S240: Use reservoir numerical simulation software to verify the well network effect under different injection and production scenarios, and generate an adaptive well network layout by combining well type classification, spatial layout and key parameters.

[0032] In a preferred embodiment of the present invention, reservoir numerical simulation software can be used to simulate the well network effect under different injection and production scenarios to verify the CO2 sweep range, recovery rate and risk control capability; then, a multi-professional review meeting is organized to review the plan, and the number of well types, layout positions and parameter settings are adjusted according to the review opinions to form the final adaptive well network layout plan.

[0033] Please refer to Figure 3 In this embodiment of the invention, constructing a multi-field coupled early warning system may include: Step S201: Based on the adaptive well network layout, plan the three-dimensional monitoring architecture between and within wells.

[0034] In a preferred embodiment of the present invention, the monitoring range between wells can cover the main CO2 migration path between the main injection well and the adjustable well. The monitoring points in the well are set in layers according to key strata such as reservoir and caprock. The monitoring priority is divided according to the risk level, and a higher collection frequency is preset in high-risk areas (e.g., near faults).

[0035] Step S202: Deploy distributed optical fibers between wells and install corresponding sensors at preset locations inside the wells.

[0036] In a preferred embodiment of the present invention, distributed optical fibers (e.g., high temperature and high pressure resistant, corrosion resistant models) can be deployed between wells and laid synchronously during drilling. They are fixed by external casing sealing to ensure close contact with the formation. CO2 concentration sensors and pressure sensors are installed at preset depth points in the monitoring or storage wells. The sensors must be resistant to formation fluid corrosion and are connected to the wellhead data acquisition terminal via dedicated cables. After installation, all equipment undergoes sealing and stability testing.

[0037] Step S203: Based on the data from distributed optical fibers and sensors, construct a multi-level data transmission link and establish a correlation mapping between monitoring data and well network location to generate a multi-field coupled early warning system.

[0038] In a preferred embodiment of the present invention, a three-level transmission link of "downhole equipment - wellhead terminal - control center" can be constructed. Downhole sensor data is transmitted to the wellhead terminal via cable. After preliminary preprocessing (e.g., noise reduction and filtering), it is transmitted to the control center via a wireless private network or optical cable. A "monitoring data - well network location" association mapping is established in the control center system to ensure that the data can be accurately located to the corresponding well network unit.

[0039] In a preferred embodiment of the present invention, static joint debugging is first performed to test the communication connectivity between the early warning system and the well network control module, verifying whether the monitoring data can accurately trigger the well network status display; then, simulated scenario testing is performed, setting typical scenarios such as "insufficient CO2 sweep around the adjustable well" and "abnormal pressure in the monitoring well" to simulate the early warning data transmission and well network control command generation process, verifying the timeliness and accuracy of the coordinated response; then, parameter calibration is performed, and based on the joint debugging results, the matching relationship between the early warning threshold and the well network control parameters is adjusted to ensure accurate coordination between the two; finally, the deployment plan is solidified, and after the joint debugging is passed, a well network layout diagram, equipment deployment list, and parameter configuration file are generated as the basis for subsequent implementation.

[0040] Step S300: Utilize the adaptive well network layout and multi-field coupled early warning system, combined with the two-way linkage mechanism of injection-production optimization-driven early warning adjustment and risk early warning-driven well network regulation, to achieve deep synergy between adaptive well network dynamic function switching and multi-field coupled early warning system monitoring.

[0041] Please refer to Figure 4 In this embodiment of the invention, the injection-progression optimization-driven early warning adjustment may include: Step S310: Based on the data collected by distributed optical fibers and combined with preset judgment criteria, monitor the oil displacement effect.

[0042] In a preferred embodiment of the present invention, based on reservoir data, core control parameters can be preset, including oil displacement compliance judgment criteria (e.g., residual oil saturation threshold, formation strain stability range, etc.), risk warning thresholds (e.g., pressure fluctuation amplitude, CO2 concentration exceeding the standard value), and well network switching trigger conditions; then the well network control equipment (e.g., wellhead valves, perforation flow regulators) are debugged to ensure smooth function switching and parameter adjustment.

[0043] In a preferred embodiment of the present invention, formation strain and temperature data collected by distributed optical fiber can be received in real time. Combined with preset judgment criteria, the remaining oil extraction situation around each adjustable well can be analyzed, and an "oil displacement effect heat map" can be formed to intuitively display the unaffected area and the area that has met the standard.

[0044] Step S320: When the oil displacement effect reaches the preset judgment standard, the collaborative control system generates and executes the well function switching command.

[0045] In a preferred embodiment of the present invention, when the surrounding area of ​​an adjustable well is detected to meet the oil displacement standard (e.g., the remaining oil saturation is ≤ a preset threshold, and the formation strain remains stable for a preset duration), the system automatically generates a well function switching command. After confirmation by the operator, the wellhead equipment is remotely controlled to switch the well from an oil production well to an injection well, and the perforation parameters of the well are adjusted to adapt to the injection requirements.

[0046] Step S330: After the well function switching command is executed, increase the sensor acquisition frequency, monitor the diffusion trend of carbon dioxide, and dynamically optimize the early warning parameters of the multi-field coupling early warning system.

[0047] In a preferred embodiment of the present invention, after the switch is completed, the system instructs the sensors around the well to increase the acquisition frequency (e.g., from once / hour to once / 10 minutes) to focus on monitoring the diffusion trend of CO2 towards the caprock or flow channels; continuously track the changes in pressure around the well, and if the pressure fluctuation is within a stable range (e.g., the pressure fluctuation amplitude is ≤ preset fluctuation amplitude), confirm that the switch is reasonable and maintain the current parameters; if the fluctuation exceeds the standard, automatically adjust the perforation flow rate to guide CO2 to migrate to the unaffected oil area.

[0048] Please refer to Figure 5 In this embodiment of the invention, risk warning-driven well network regulation may include: Step S301: Analyze the data from the distributed optical fiber and sensors. When abnormal pressure changes are detected and carbon dioxide concentration rises abnormally at the same time, it is determined to be a risk of crossflow and a graded warning is triggered.

[0049] In a preferred embodiment of the present invention, data from distributed optical fiber, CO2 concentration sensor and pressure sensor can be analyzed in real time. When an abnormal change in pressure (e.g., a sudden drop ≥ the warning threshold) and a synchronous abnormal increase in CO2 concentration are detected, it is automatically determined to be a risk of crossflow and triggers a graded warning (e.g., a first-level warning is a potential risk and a second-level warning is a crossflow that has already occurred).

[0050] Step S302: Based on the triggered graded early warning, generate and execute well network emergency control instructions through the collaborative control system, and push early warning information for user confirmation.

[0051] In a preferred embodiment of the present invention, for example, after a level-two warning is triggered, the system immediately generates a control command: shuts down the main injection well or adjustable injection well upstream of the crossflow channel to cut off the CO2 supply; switches the downstream adjustable well to an oil production well to form a negative pressure diversion effect and prevent further CO2 crossflow; and pushes the warning information to the operator to prompt on-site confirmation.

[0052] Step S303: After the user confirms the warning information, the preset isolation zone is temporarily blocked and reinforced.

[0053] In a preferred embodiment of the present invention, after the operator confirms the risk, a quick-setting gel is injected into the isolation zone through a pre-set isolation zone sealing well (e.g., a monitoring or sealing well). The system monitors the gel injection pressure and diffusion range in real time to ensure the formation of a continuous temporary sealing barrier. After the sealing is completed, the CO2 concentration and pressure changes in the crossflow area are monitored to confirm that the risk has been contained.

[0054] In a preferred embodiment of the present invention, the oil displacement effect can be evaluated periodically (e.g., weekly), and indicators such as the recovery rate improvement and CO2 spread range can be statistically analyzed; then, risk management cases can be analyzed to summarize data such as early warning response time and plugging success rate; finally, based on the evaluation results, the oil displacement compliance judgment criteria, early warning thresholds and well network switching parameters can be iteratively optimized to improve the accuracy of regulation.

[0055] Step S400: After confirming that the oil displacement effect in the target reservoir area meets the standard, a continuous sealing barrier is constructed for the target reservoir area using directional isolation technology.

[0056] Please refer to Figure 6 In this embodiment of the invention, constructing a continuous sealing barrier for a target reservoir area using directional isolation technology may include: Step S410: Combining reservoir data, injection-production optimization data, and carbon dioxide distribution monitoring results, the boundary between the oil displacement zone and the storage zone is delineated using numerical simulation methods.

[0057] In a preferred embodiment of the present invention, a final evaluation of the oil displacement effect can be conducted first, summarizing the injection and production data and residual oil monitoring data during the control phase to confirm that the recovery rate of the entire block has reached the preset target and that it is ready for storage. Then, the storage boundary is delineated. Combining the reservoir geological model, mid-term injection and production data, and CO2 distribution monitoring results, the boundary between the "oil displacement zone and storage zone" is accurately delineated through numerical simulation, clarifying the width and range of the isolation zone. Finally, materials and equipment are prepared, such as solidifiable gel, low-viscosity gel, and high-strength gel, and sealing materials are purchased. The storage monitoring equipment and gel injection equipment are debugged to ensure stable performance.

[0058] Step S420: According to the defined boundary, inject curable gel into the isolation zone through the preset sealing well to form a continuous sealing barrier.

[0059] In a preferred embodiment of the present invention, the isolation zone can be sealed first. Based on the boundary delineation results, a curable gel is injected uniformly into the isolation zone through a preset sealing well (monitoring or storage well). During the injection process, the gel diffusion range and injection pressure are monitored in real time to ensure that the gel uniformly fills the pores of the isolation zone and forms a continuous sealing barrier. Then, the barrier integrity is tested. The sealing effect of the isolation zone is tested using technologies such as sonic logging and pressure testing. If there are leaks, more gel is injected until the standard is met. Then, the well function is converted, and the original main injection well is switched to a storage monitoring well. The wellhead monitoring equipment is upgraded and connected to a multi-field coupling early warning system, with a 24-hour monitoring and reminder function configured. Finally, the initial state of storage is recorded, and the initial CO2 concentration and pressure data of the storage area are collected to establish a storage baseline database.

[0060] Step S430: Using a preset sealing test technology, the integrity of the continuous sealing barrier is tested. If a leak is detected, a curable gel is injected until the standard is met.

[0061] In a preferred embodiment of the present invention, after the multi-field coupling early warning system detects that the CO2 concentration exceeds the standard, the location and scale of the leak are accurately located by cross-analysis of monitoring data from multiple wells (e.g., the time difference of concentration changes in different monitoring wells). Then, low-viscosity gel is injected into the leak point through the nearest storage monitoring well, utilizing its high fluidity to quickly penetrate and fill the leak channel, initially curbing the leak. Next, the adjustable wells around the leak point are switched to auxiliary injection wells, injecting CO2 to form a directional pressure difference, driving the leaked CO2 back to the storage area. When the CO2 concentration is detected to have returned to the safe threshold, the injection of low-viscosity gel is stopped, and high-strength gel is injected into the leak point and surrounding area to form a permanent reinforcement layer. Finally, the sealing effect of the leak point is tested, monitoring data is added to the storage database, the cause of the leak is analyzed, and subsequent monitoring parameters are optimized.

[0062] Step S500: Utilize a multi-field coupling early warning system to monitor the long-term sealing barrier, forming a pre-set storage guarantee system to achieve stable carbon dioxide storage.

[0063] Please refer to Figure 7 In this embodiment of the invention, a multi-field coupling early warning system is used to monitor the long-term sealing barrier, forming a preset sealing protection system, which may include: Step S510: Use a multi-field coupling early warning system to collect multi-source data from the storage area at a preset frequency.

[0064] In a preferred embodiment of the present invention, routine monitoring can be performed. The multi-field coupling early warning system collects CO2 concentration, pressure and caprock strain data in the sealing area at a preset frequency. The data is transmitted to the control center in real time, and the system automatically compares the sealing baseline to identify abnormal changes.

[0065] Step S520: Conduct inspections of the sealing monitoring wells, isolation zones, and early warning equipment according to the preset cycle.

[0066] In a preferred embodiment of the present invention, the sealing monitoring well, isolation zone and early warning equipment can be inspected on-site every month to check the equipment operation status, wellhead sealing and whether there are any abnormalities on the surface of the isolation zone (e.g. bulges, cracks, etc.).

[0067] Step S530: Summarize monitoring data according to a preset time period, predict the long-term stability of carbon dioxide storage through numerical simulation, and generate a storage monitoring report.

[0068] In a preferred embodiment of the present invention, when performing periodic data analysis, for example, monitoring data is summarized every quarter, and the long-term storage stability of CO2 is predicted through numerical simulation, the trend of caprock integrity changes is assessed, and a storage monitoring report is generated.

[0069] Step S600: Utilize the SCADA control system to integrate the data flow and command flow of the collaborative control system, perform closed-loop command execution through a dedicated linkage module, and iteratively optimize the parameters of the collaborative control system based on the operating data of the SCADA control system.

[0070] Please refer to Figure 8 In this embodiment of the invention, the SCADA control system integrates the data flow and command flow of the collaborative control system, and performs closed-loop command execution through a dedicated linkage module, which may include: Step S610: Deploy the SCADA control system, integrate the data flow and command flow of each link of the collaborative control system, and realize closed-loop management of data-command-execution-feedback.

[0071] Step S620: Develop a dedicated linkage module for early warning and control, which converts the monitoring data (e.g., pressure, concentration anomalies, etc.) of the multi-field coupled early warning system into executable commands for well network control (e.g., switching well functions, adjusting injection volume, etc.).

[0072] Step S630: Set hierarchical operation permissions (e.g., operators, administrators), configure data encryption and logging functions to ensure that the operation of the SCADA control system is traceable and the data is secure and controllable.

[0073] In a preferred embodiment of the present invention, the operating data of the SCADA control system may include geological and initial state data during the data acquisition phase, well network and early warning equipment parameters, injection and production effect and risk management data during the control phase, and storage monitoring and emergency response data during the storage phase. The data is then stored in a distributed database, and a directory structure is established according to "phase-date-data type" to ensure convenient data retrieval. Finally, an off-site data backup mechanism is established to back up core data regularly (e.g., daily) to prevent data loss.

[0074] In a preferred embodiment of the present invention, abnormal data can be automatically cleaned, and big data analysis technology can be used to mine data correlation patterns (e.g., the correlation between injection and production parameters and recovery rate, and the relationship between early warning threshold and false alarm rate). Based on the analysis results, key parameters are iteratively adjusted, including: well network deployment parameters (e.g., adjustable well spacing), early warning threshold (e.g., pressure anomaly judgment criteria), gel injection volume (e.g., isolation zone plugging concentration), and injection and production parameters (e.g., injection pressure and flow rate). Finally, based on the parameter optimization results, the well network control scheme, early warning deployment scheme, and emergency response plan are updated to ensure that the scheme continuously adapts to dynamic changes in the reservoir (e.g., formation stress changes and pore structure evolution).

[0075] In a preferred embodiment of the present invention, the optimized parameters can be tested on a small scale in a portion of the target reservoir area (e.g., a well group) to monitor the oil displacement efficiency, storage stability and early warning accuracy of the test area; then compare the core indicators before and after the test (e.g., recovery rate improvement, leakage rate, false alarm rate, etc.) to evaluate the optimization effect; if the test results meet the standards, the optimized scheme can be promoted to the entire block.

[0076] On the other hand, embodiments of the present invention also provide a coordinated control system for carbon dioxide enhanced oil recovery and underground storage. The coordinated control system includes a control module, which includes a memory, a processor, and a computer program stored in the memory and executable on the processor. The processor executes the computer program to implement the coordinated control method described above.

[0077] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0078] This application is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of this application. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart... Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0079] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0080] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0081] In a typical configuration, a computing device includes one or more processors (CPU), input / output interfaces, network interfaces, and memory.

[0082] Memory may include non-persistent memory in computer-readable media, such as random access memory (RAM) and / or non-volatile memory, like read-only memory (ROM) or flash RAM. Memory is an example of computer-readable media.

[0083] Computer-readable media includes both permanent and non-permanent, removable and non-removable media that can store information using any method or technology. Information can be computer-readable instructions, data structures, modules of programs, or other data. Examples of computer storage media include, but are not limited to, phase-change memory (PRAM), static random access memory (SRAM), dynamic random access memory (DRAM), other types of random access memory (RAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), flash memory or other memory technologies, CD-ROM, digital versatile optical disc (DVD) or other optical storage, magnetic tape, magnetic disk storage or other magnetic storage devices, or any other non-transferable medium that can be used to store information accessible by a computing device. As defined herein, computer-readable media does not include transient computer-readable media, such as modulated data signals and carrier waves.

[0084] It should also be noted that the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such process, method, article, or apparatus. Unless otherwise specified, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes that element.

[0085] The above are merely embodiments of this application and are not intended to limit the scope of 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 spirit and principles of this application should be included within the scope of the claims of this application.

Claims

1. A method for synergistic control of carbon dioxide enhanced oil recovery and underground sequestration, characterized in that, The collaborative control method includes: Using geological exploration techniques, basic reservoir data of the reservoir geological model is collected. Based on sensors deployed in the target reservoir area, initial state data is collected and standardized to obtain reservoir data. Based on reservoir data, an adaptive well network layout was designed, and a multi-field coupled early warning system was constructed to match the well network function with early warning monitoring. By utilizing an adaptive well network layout and a multi-field coupled early warning system, combined with a two-way linkage mechanism that drives early warning adjustment through injection and production optimization and drives well network regulation through risk early warning, a deep synergy between the adaptive well network dynamic function switching and the monitoring of the multi-field coupled early warning system can be achieved. After confirming that the oil displacement effect in the target reservoir area meets the standards, a continuous sealing barrier is constructed for the target reservoir area using directional isolation technology; By utilizing a multi-field coupling early warning system, long-term sealing barriers are monitored to form a pre-set storage guarantee system, thereby achieving stable carbon dioxide storage.

2. The collaborative control method according to claim 1, characterized in that, The adaptive well network layout design includes: Based on the reservoir characteristics and development needs in the reservoir data, well types are classified; Based on the remaining oil distribution data in the reservoir data, a spatial layout is designed; Based on the potential crossflow channels in the reservoir data, key parameters are preset; Using reservoir numerical simulation software, the well pattern effect under different injection and production scenarios is verified, and an adaptive well pattern layout is generated by combining well type classification, spatial layout and key parameters.

3. The cooperative control method according to claim 2, characterized in that, The construction of the multi-field coupled early warning system includes: Based on the adaptive well network layout, plan a three-dimensional monitoring architecture between and within wells; Distributed optical fibers are deployed between wells, and corresponding sensors are installed at preset locations inside the wells; Based on data from distributed optical fibers and sensors, a multi-level data transmission link is constructed, and a correlation mapping between monitoring data and well network location is established to generate a multi-field coupled early warning system.

4. The collaborative control method according to claim 1, characterized in that, The injection and production optimization-driven early warning adjustment includes: Based on data collected by distributed optical fibers and combined with preset judgment criteria, the oil displacement effect is monitored. When the oil displacement effect reaches the preset judgment criteria, the collaborative control system generates and executes the well function switching command; After the well function switching command is executed, the sensor acquisition frequency is increased to monitor the diffusion trend of carbon dioxide and dynamically optimize the early warning parameters of the multi-field coupling early warning system.

5. The cooperative control method according to claim 4, characterized in that, The risk warning-driven well network regulation includes: By analyzing data from distributed optical fibers and sensors, when abnormal pressure changes are detected and carbon dioxide concentration rises abnormally at the same time, it is determined to be a risk of cross-flow and a graded warning is triggered. Based on the triggered graded early warnings, the collaborative control system generates and executes emergency control commands for the well network, and pushes early warning information for user confirmation. After the user confirms the warning information, the preset isolation zone is temporarily blocked and reinforced.

6. The cooperative control method according to claim 1, characterized in that, The method of constructing a continuous sealing barrier for the target reservoir area using directional isolation technology includes: Combining reservoir data, injection-production optimization data, and carbon dioxide distribution monitoring results, the boundary between the oil displacement zone and the storage zone was delineated using numerical simulation methods. According to the defined boundaries, solidifiable gel is injected into the isolation zone through pre-designated sealing wells to form a continuous sealing barrier; Using a pre-defined sealing test technique, the integrity of the continuous sealing barrier is tested. If a leak is detected, a curable gel is injected until the standard is met.

7. The cooperative control method according to claim 6, characterized in that, The aforementioned multi-field coupling early warning system monitors the long-term sealing barrier, forming a pre-set sealing protection system, including: A multi-field coupling early warning system is used to collect multi-source data from the storage area at a preset frequency. The sealed monitoring wells, isolation zones, and early warning equipment shall be inspected according to the preset cycle. Monitoring data are compiled according to a preset time period, and the long-term stability of carbon dioxide storage is predicted through numerical simulation to generate a storage monitoring report.

8. The cooperative control method according to claim 1, characterized in that, The collaborative control method further includes: By utilizing the SCADA control system, the data flow and command flow of the collaborative control system are integrated. Through a dedicated linkage module, the commands are executed in a closed loop, and the parameters of the collaborative control system are iteratively optimized based on the operating data of the SCADA control system.

9. The cooperative control method according to claim 1, characterized in that, The method of utilizing a SCADA control system to integrate the data flow and command flow of a collaborative control system, and performing closed-loop command execution through a dedicated linkage module, includes: Deploy a SCADA control system to integrate the data and command flows of each link in the collaborative control system, and realize closed-loop management of data-command-execution-feedback; Develop a dedicated early warning-control linkage module to convert monitoring data from multi-field coupled early warning systems into executable well network control commands; Set up tiered operation permissions, configure data encryption and logging functions to ensure that the operation of the SCADA control system is traceable and the data is secure and controllable.

10. A synergistic control system for carbon dioxide enhanced oil recovery and underground storage, characterized in that, The collaborative control system includes a control module, which includes a memory, a processor, and a computer program stored in the memory and executable on the processor. The processor executes the computer program to implement the collaborative control method according to any one of claims 1-9.

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