Wireless testing and adjusting method, device and equipment for injection allocation shaft

Abstract

The invention relates to the field of oil well detection systems, in particular to a wireless testing and adjusting method, device and equipment for an injection allocation shaft. The wireless testing and adjusting method for the injection allocation shaft comprises the steps that underground environment data collected by an underground sensor are coded, and uplink coded data are obtained; the opening degree of an annulus throttling valve is controlled according to the ascending coded data, so that the protection liquid in the annulus forms ascending pressure waves; upstream pressure waves of the protection liquid in the annulus are detected, and upstream coded data are obtained; and analyzing the uplink coded data to obtain the underground environment data. According to the embodiment of the invention, the pressure wave signal can be better transmitted in a low-pressure manner by using the annulus protection liquid, so that the fine degree of wireless measurement and adjustment of the CO2 injection amount of each oil layer in a CO2 injection well scene can be improved, and the method has important significance in improving the transmission effect of the pressure wave signal in the CO2 injection well scene and identifying the wireless measurement and adjustment risk of the CO2 injection well.

Description

Technical Field

[0001] The embodiments of the present invention relate to the field of oil well detection systems, and specifically to a method, device and equipment for wireless detection and adjustment of injection wellbore. Background Art

[0002] As the main terminal neutralization method, carbon dioxide capture, utilization and storage (CCUS) has great development potential in the process of achieving energy conservation and emission reduction. CO2 flooding can achieve the dual goals of resource utilization of greenhouse gases and improving oil recovery, and is the main position for the implementation of CCUS. Among them, gas injection technology is a key component of CO2 flooding. With the development of technology, gas injection technology has shifted from conventional general gas injection to stratified gas injection. However, due to the influence of formation pressure or porosity, the amount of CO2 injected into each oil layer is different, so it is necessary to finely control the amount of CO2 injected to improve oil recovery.

[0003] The injection process is developing in the direction of intelligence, mainly based on the cable-type layered gas injection process. The cable-type intelligent layered gas injection equipment mainly includes cable-type intelligent gas distributors, cable-through packers and ground control systems. Each gas injection layer corresponds to an intelligent gas distributor, which is connected to the ground control system by cables, and the gas injection volume of each layer is controlled by controlling the opening of the gas nozzle. Although this process has the advantages of real-time adjustment of gas injection volume and convenient operation, it has problems such as high construction quality requirements, high cost, and large flow measurement errors. Therefore, how to achieve low-cost and high-quality downhole data transmission is a key issue that needs to be solved urgently. Summary of the invention

[0004] The purpose of the embodiments of this specification is to provide a method, device and equipment for wireless measurement and adjustment of injection wellbore to reduce the cost of underground communication and reduce the error rate of underground communication.

[0005] On the one hand, an embodiment of the present specification proposes a method for wireless measurement and adjustment of an injection wellbore, the method comprising: encoding the downhole environmental data collected by the downhole sensor to obtain uplink coded data; controlling the opening of the annulus throttle valve according to the uplink coded data so that the protective fluid in the annulus forms an upward pressure wave; detecting the upward pressure wave of the protective fluid in the annulus to obtain uplink coded data; and parsing the uplink coded data to obtain the downhole environmental data.

[0006] On the other hand, a wireless measurement and adjustment device for an injection wellbore is provided, the device comprising: a coding module for encoding downhole environmental data collected by downhole sensors to obtain uplink coded data; a control module for controlling the opening of the annulus throttle valve according to the uplink coded data so that the protective fluid in the wellbore annulus forms an upward pressure wave; a detection module for detecting the upward pressure wave of the protective fluid in the wellbore annulus to obtain uplink detection data; and an analysis module for analyzing the uplink detection data to obtain the downhole environmental data.

[0007] On the other hand, a computer device is provided, including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the above-mentioned wireless measurement and adjustment method for injection wellbore.

[0008] It can be seen from the technical solutions provided in the above embodiments of this specification that the embodiments of this specification encode the downhole environmental data collected by the downhole sensor to obtain uplink coded data; control the opening of the annular throttle valve according to the uplink coded data so that the protective fluid in the annulus forms an uplink pressure wave; detect the uplink pressure wave of the protective fluid in the annulus to obtain uplink coded data; and parse the uplink coded data to obtain the downhole environmental data. The protective fluid in the annulus is used to protect the injection wellbore from corrosion, scaling, bacterial growth and other problems. In the embodiments of this specification, the protective fluid in the annulus is used as a carrier for data transmission, and data is transmitted through the pressure wave of the protective fluid in the annulus, thereby realizing downhole wireless communication at a low cost. In addition, the compressibility of the protective fluid in the annulus is poor, and it is difficult for the volume to change significantly under the action of external force. By utilizing the poor compressibility of the protective fluid, the stability of data transmission can be improved and the error rate during data transmission can be reduced. The technical solution of the embodiments of this specification can improve the precision of wireless measurement and adjustment of CO2 injection amount in each oil layer in the CO2 injection well scenario, which is of great significance for improving the transmission effect of pressure wave signals in the CO2 injection well scenario and wireless measurement and adjustment and risk identification of CO2 injection wells. BRIEF DESCRIPTION OF THE DRAWINGS

[0009] In order to more clearly illustrate the technical solutions in the embodiments of this specification or the prior art, the drawings required for use in the embodiments or the prior art description are briefly introduced below.

[0010] Figure 1 It is a flow chart of a wireless measurement and adjustment method for injection wellbore provided in an embodiment of this specification;

[0011] Figure 2 It is a schematic diagram of the structure of the wireless measurement and adjustment surface equipment and downhole equipment for injection wellbore provided in the embodiments of this specification;

[0012] Figure 3 It is a flow chart of the method for downhole testing and adjustment of injection wellbore provided in the embodiment of this specification;

[0013] Figure 4 It is a schematic diagram of the structure of a wireless measurement and adjustment device for injection wellbore provided in an embodiment of this specification;

[0014] Figure 5 It is a schematic diagram of the structural composition of a computer device provided in an embodiment of this specification.

[0015] Reference numerals in the above drawings:

[0016] 1. Ground controller; 2. Downhole injector; 3. Oil pipe; 4. Packer; 5. Annulus protection fluid; 6. Downhole sensor; 7. CO2 fluid; 8. Annulus throttle valve. DETAILED DESCRIPTION

[0017] The following will be combined with the drawings in the embodiments of this specification to clearly and completely describe the technical solutions in the embodiments of this specification. Obviously, the described embodiments are only part of the embodiments of this specification, not all of the embodiments. Based on the embodiments in this specification, all other embodiments obtained by ordinary technicians in this field without creative work should fall within the scope of protection of this specification.

[0018] In the related art, downhole wireless communication can be achieved through pressure wave downhole data transmission technology. Pressure wave transmission does not occupy the oil pipe channel, and the pressure sensor can be used as a downhole monitoring and data transmission sensor at the same time. However, due to the strong compressibility of CO2, the pressure wave signal transmission effect is not ideal. Therefore, the above-mentioned pressure wave transmission technology is rarely used in wireless transmission of downhole signals in CO2 injection wells. It should be noted that the above introduction to the technical background is only for the convenience of a clear and complete description of the technical solution of the present application and for the convenience of understanding by those skilled in the art.

[0019] Figure 1 The following is a flow chart of the wireless measurement and adjustment method for injection wellbore. In specific implementation, the method includes the following steps:

[0020] S101: Encode the downhole environment data collected by the downhole sensor to obtain uplink encoded data.

[0021] In some embodiments, the downhole sensor may include a temperature sensor, a pressure sensor, a flow sensor, and a displacement sensor. The temperature sensor can collect temperature data of the tubing and the annulus in real time. The pressure sensor can collect pressure data of the tubing and the annulus in real time. The flow sensor can collect flow data of the tubing and the annulus in real time. The displacement sensor can collect wellbore deformation data in real time. The collected downhole environmental data can be encoded by using PPM coding, UWB coding, or other coding techniques to obtain uplink coded data. PPM coding can use different pulse positions to represent different binary data. UWB coding can use Gaussian single-cycle ultra-short-time pulses to carry information. For example, the collected downhole environmental data can be converted into binary representation, and then pulse signals at different positions are generated by PPM coding to represent the downhole environmental data, and then uplink coded data can be obtained.

[0022] In some embodiments, before encoding the downhole environmental data collected by the downhole sensor to obtain the uplink encoded data, multiple downhole dispensers, multiple downhole sensors and other equipment can be lowered into the wellbore along with the pipe string; after the pipe string is lowered into the wellbore, CO2 (carbon dioxide) can be injected into each oil layer; and the CO2 injection amount data of each oil layer during the CO2 injection process can be obtained. Figure 2 As shown, the upper wellbore is filled with annular protection fluid 5, and the wellbore of the gas injection layer is filled with CO2 fluid 7. Multiple downhole dispensers 2 can be connected to the designated gas injection layer of the injection well in sequence through the oil pipe 3, and the bottom of the wellbore is connected to the annular throttle valve 8. The downhole dispenser 2 at the upper end of each gas injection layer is connected to the packer 4 through the oil pipe 3. The downhole sensor 6 on each downhole dispenser 2 supports the monitoring of downhole environmental data such as downhole temperature data, pressure data, flow data, and well wall deformation data. The ground controller 1 communicates with each downhole dispenser 2 and the downhole sensor 6 in a wireless wave code communication mode. The ground controller 1 can monitor and control the collected data of the downhole dispenser 2 corresponding to each oil layer in real time through the wireless wave code communication mode, and then analyze the collected data of each layer and generate control instructions. The ground controller 1 can wirelessly control multiple downhole dispensers 2 to inject CO2 into each oil layer through control instructions, and can save the CO2 injection amount data during the CO2 injection process of each oil layer.

[0023] In some embodiments, the downhole environmental data may include at least temperature data, pressure data, flow data and wellbore deformation data of the tubing, casing and annulus. The temperature data may characterize the temperature state and temperature change trend of the tubing, casing and annulus; the pressure data may characterize the pressure state and pressure change trend of the tubing, casing and annulus; the flow data may characterize the flow state and flow change trend in the tubing, casing and annulus; and the wellbore deformation data may characterize the deformation degree and deformation trend of the wellbore.

[0024] In some embodiments, downhole environmental data may be affected by a variety of factors during the acquisition process, such as environmental factors, equipment accuracy, human operation, etc., resulting in errors in the data. In addition, outliers may also appear. Outliers are data points that are significantly different from other data points. They may be caused by measurement errors, equipment failures, or extreme conditions. Data collected from different data sources or at different times may also have different formats and units, and the original data may also contain repeated or redundant information.

[0025] Based on the above situation, the collected raw data needs to be processed, including digital modeling, filtering, and unit conversion. Data modeling can be performed on the collected temperature data, pressure data, flow data, and wellbore deformation data, and then filters can be used to filter and pre-segment the raw data collected by downhole sensors, and at the same time, unified into international standard units to facilitate subsequent data storage and use. Through data modeling, filtering, unit conversion and other processing methods, data quality can be improved, data consistency can be ensured, data analysis efficiency can be improved, and specific needs can be met.

[0026] S102: Control the opening of the annular throttle valve according to the upward coded data, so that the protective fluid in the annular space forms an upward pressure wave.

[0027] In some embodiments, in order to separate different geological strata and prevent the wellbore from collapsing due to different formation pressures, casing cementing is required. The casing is cemented with cement, and the annular space between the tubing and the casing can be called an annulus. There is an annular protection fluid in the annulus. The annular protection fluid is a type of brine solution or oily solvent containing additives such as corrosion inhibitors, bactericides, and deoxidizers, which can inhibit the corrosion of the tubing and casing. The pressure of the annular space between the tubing and the casing is called annular pressure. The annular throttle valve can control the annular pressure by adjusting the opening. When the annular throttle valve opening is adjusted, the flow rate of the annular protection fluid changes and generates fluctuating pressure, which can propagate along the annulus. A mapping relationship between the coded data and the opening size can be established, and the uplink coded data can be substituted into the established mapping relationship, and then the uplink target opening of the annular throttle valve can be obtained. The opening of the annular throttle valve can be adjusted to the uplink target opening, changing the flow rate of the annular protection fluid, and generating an uplink pressure wave that propagates upward along the annulus. For example, the friction coefficient between the annular protection fluid and the tubing and casing, the elastic coefficient of the tubing and casing wall, and the elastic coefficient of the annular protection fluid and other influencing factors can be comprehensively considered to establish a multivariate linear or nonlinear mapping relationship between the coded data and the opening size. The uplink coded data can be substituted into the established multivariate linear or nonlinear mapping relationship to obtain the uplink target opening sequence of the annular throttle valve corresponding to each uplink coded data. The opening of the annular throttle valve can be continuously adjusted according to the obtained uplink target opening sequence, the flow rate of the annular protection fluid can be changed, and an uplink pressure wave propagating upward along the annulus can be generated.

[0028] For example, the uplink coded data has a plurality of bits, each of which has a bit value. The uplink coded data may be a bit value sequence formed in sequence by the plurality of bit values. The opening of the annular throttle valve may be controlled according to each bit value in the bit value sequence and the timing of the bit values, so that the protective fluid in the annular space forms an uplink pressure wave corresponding to the bit value sequence.

[0029] For example, the injection string may be provided with a plurality of downhole injectors and a downhole controller corresponding to the plurality of downhole injectors. Each downhole injector corresponds to a formation or oil layer. Layered injection can be achieved by using the plurality of downhole injectors. Each downhole injector is provided with a downhole sensor, a downhole encoder and a downhole controller, wherein the downhole sensor is used to collect downhole environmental data such as pressure, temperature, flow rate, etc. of the downhole injector, and the downhole encoder is used to encode the downhole environmental data of the downhole injector to obtain uplink encoded data. The downhole encoder can send the encoded uplink encoder to the downhole controller so that the downhole controller can control the opening of the annulus throttle valve according to the uplink encoded data.

[0030] Optionally, the downhole encoder can also encode the downhole environment data of the downhole dispenser and the identification information of the downhole dispenser to obtain the uplink coded data. The downhole controller can control the opening of the annular throttle valve according to the uplink coded data. Therefore, after parsing the uplink coded data to obtain the downhole environment data, the downhole dispenser to which the downhole environment data belongs can be determined, thereby determining the formation or oil layer corresponding to the downhole environment data.

[0031] By using annular protection fluid in the annulus, on the one hand, the oil and gas pressure on the packer can be reduced, the packer can be prevented from leaking, and the pressure difference between the tubing and the annulus can be reduced. In addition, the corrosion resistance of the annular protection fluid can inhibit the corrosion tendency of the tubing and casing. On the other hand, considering the incompressibility and stability of the annular protection fluid, it can be used as a data carrier to stably transmit data. In addition, data transmission with the help of annular protection fluid does not require additional costs and the accuracy of data transmission is greatly improved.

[0032] S103: Detect the upward pressure wave of the protective fluid in the wellbore annulus to obtain upward coded data.

[0033] In some embodiments, a pressure sensor can be set on the ground, and the ground pressure sensor can detect the upward pressure wave generated by adjusting the opening of the annular throttle valve, and can obtain the upward coded data according to the upward pressure wave. The upward pressure wave may also be affected by various factors during the transmission process, such as environmental factors, equipment accuracy, human operation, etc., which may lead to slight deviations between the obtained upward detection data and the actual upward coded data. The ground controller can process the upward detection data by filtering, data modeling, data screening and other data processing methods to obtain the upward coded data. For example, for the upward detection data with normal distribution noise, the upward detection data can be processed by a Gaussian low-pass filter to obtain the upward coded data. For another example, the influence of factors such as the friction coefficient between the annular protection fluid and the tubing and the casing, the elastic coefficient of the tubing and the casing wall, and the elastic coefficient of the annular protection fluid on the upward detection data can be considered, and a multivariate linear or nonlinear mapping relationship between the detection data and the coded data is established. The upward detection data can be substituted into the established multivariate linear or nonlinear mapping relationship to obtain the upward coded data.

[0034] S104: Parse the uplink coded data to obtain the downhole environment data.

[0035] In some embodiments, the ground controller can use a decoding technology that is compatible with the encoding technology used when encoding the downhole environmental data to parse the uplink encoded data and recover the downhole environmental data. For example, the downhole environmental data is encoded using PPM encoding to obtain the uplink encoded data, and then the different positions of the pulse can be detected to obtain the decoded binary data representation, and the downhole environmental data can be obtained by parsing the obtained binary data representation. For another example, the downhole environmental data is encoded using UWB encoding to obtain the uplink encoded data, and then the Gaussian single-cycle ultra-short-time pulse can be detected to obtain the decoded binary data representation, and the downhole environmental data can be obtained by parsing the obtained binary data representation.

[0036] By encoding the monitored downhole environmental data and transmitting it to the ground controller through the annulus protection fluid, detailed environmental information of the oil pipe and annulus can be obtained, laying the foundation for fine-grained wireless adjustment of the CO2 injection amount of each oil layer.

[0037] In some embodiments, after parsing the uplink detection data to obtain the downhole environmental data, a downlink control instruction can be generated based on the downhole environmental data; the downlink control instruction is encoded to obtain downlink coded data; the opening of the annulus throttle valve is controlled according to the downlink coded data so that the protective fluid in the wellbore annulus forms a downward pressure wave; the downward pressure wave of the protective fluid in the wellbore annulus is detected to obtain the control instruction; and the opening of the downhole injector is adjusted according to the control instruction to adjust the CO2 injection amount of each oil layer.

[0038] Figure 3 The method is a flow chart for fine control of injection wellbore. In specific implementation, the method includes the following steps:

[0039] S301: Generate a downlink control instruction according to the downhole environment data.

[0040] In some embodiments, before generating downlink control instructions based on the downhole environmental data, historical downhole environmental data, historical CO2 injection volume data of each oil layer and historical risk perception data can also be obtained; based on the historical downhole environmental data and the historical CO2 injection volume data of each oil layer, a working condition perception prediction model can be constructed; based on the historical downhole environmental data and the historical risk perception data, a risk perception prediction model can be constructed.

[0041] By constructing the working condition perception prediction model and the risk perception prediction model, a real-time and accurate judgment basis can be provided for the subsequent wireless measurement and adjustment of the CO2 injection amount of each oil layer and risk warning suggestions.

[0042] The historical downhole environmental data may at least include the historical temperature data, historical pressure data, historical flow data and historical wellbore deformation data of the tubing, casing and annulus. Among them, the historical temperature data can characterize the historical temperature state and historical temperature change trend of the tubing, casing and annulus; the historical pressure data can characterize the historical pressure state and historical pressure change trend of the tubing, casing and annulus; the historical flow data can characterize the historical flow state and historical flow change trend in the tubing, casing and annulus; the historical wellbore deformation data can characterize the historical deformation degree and historical deformation trend of the wellbore. The historical risk perception data can be classified with at least two labels. For example, the historical risk perception data can be set to 0 and 1, indicating the small and large risks respectively, or it can be set to multiple levels according to a certain logical relationship and more detailed and accurate, which will not be repeated here. Each set of historical downhole environmental data corresponds to a set of historical CO2 injection volume data and historical risk perception data for each oil layer.

[0043] Based on the historical downhole environmental data and the historical CO2 injection volume data of each oil layer, a working condition perception prediction model can be constructed. For example, the historical downhole environmental data and the historical CO2 injection volume data of continuous historical time points can be used as input parameters of the working condition perception prediction model to predict the historical downhole environmental data and the historical CO2 injection volume data of the next historical time point of the continuous historical time point. For another example, the historical downhole environmental data and the historical CO2 injection volume data of all historical time points in a certain historical time period can be preprocessed to obtain the historical downhole environmental data and the historical CO2 injection volume data that can characterize the entire historical time period, and use them as input parameters of the working condition perception prediction model to predict the historical downhole environmental data and the historical CO2 injection volume data of the next historical time period. The working condition perception prediction model can be trained based on the predicted historical downhole environmental data and the historical CO2 injection volume data and the actual historical downhole environmental data and the historical CO2 injection volume data.

[0044] Based on the historical downhole environment data and the historical risk perception data, a risk perception prediction model can be constructed. For example, the historical downhole environment data at a certain historical time point can be used as an input parameter of the risk perception model to predict the historical risk perception data at the next historical time point. The risk perception prediction model can be trained based on the predicted historical risk perception data and the actual historical risk perception data.

[0045] When any of the deep learning models in the above working condition perception prediction model and risk perception prediction model is trained, the learning rate update process is as follows:

[0046] During the training process, gradient descent is used to update the deep learning model parameters according to the gradient descent algorithm of the Newton-Leibniz formula. The calculation formula is:

[0047]

[0048] In the formula, ωj represents the jth parameter of the deep learning model, ωj' is the corresponding updated parameter; λ represents the learning rate of the deep learning model, which is used to determine the convergence rate of the deep learning model; It represents the partial derivative of the loss function F(ωj) with respect to ωj when the deviation between the predicted result and the actual result of the deep learning model is known. The deviation between the predicted result and the actual result can be calculated by the loss function; the loss function is usually defined based on the sum of squared errors between the predicted result and the actual result or the absolute value of the error, logarithmic loss, and other methods. The deep learning model adjusts the values ​​of each parameter in the model by the deviation between the predicted result and the actual result, so that the deviation becomes smaller and smaller. The deep learning model used in the geothermal parameter prediction model and the geothermal resource evaluation model can specifically adopt RNN, LSTM, GRU, Transformer and other models.

[0049] The learning rate can be set to a fixed value, or adopt strategies such as learning rate decay, adaptive learning rate, and polynomial learning rate. The idea of ​​learning rate decay is to gradually reduce the learning rate as training progresses to improve the stability and generalization ability of model training. Adaptive learning rate is a type of strategy that can automatically adjust the learning rate. It can dynamically adjust the learning rate according to the gradient information of the parameters, thereby improving the training speed and performance of the model. The idea of ​​polynomial decay is to decay the learning rate through a polynomial function, thereby gradually reducing the learning rate during training. It can help the model converge better in the later stages of training and improve the generalization ability of the model.

[0050] In some embodiments, generating downlink control instructions based on the downhole environmental data may include: inputting the downhole environmental data and the CO2 injection amount data of each oil layer into a working condition perception prediction model to predict working condition perception data; and generating downlink control instructions based on the predicted working condition perception data.

[0051] By using the condition-aware prediction model, the downhole environment can be better characterized, thereby providing more refined CO2 injection guidance for each downhole oil layer.

[0052] For example, when the input parameters of the working condition perception prediction model are the downhole environment data and CO2 injection amount data at continuous time points, the downhole environment data and CO2 injection amount data at continuous time points before the next time point can be input into the working condition perception prediction model to predict the downhole environment data and CO2 injection amount data at the next time point. According to the predicted CO2 injection amount data at the next time point, a downlink control instruction for controlling the CO2 injection amount of each oil layer at the next time point can be generated. For another example, when the input parameters of the working condition perception prediction model are the downhole environment data and CO2 injection amount data within a time period, the downhole environment data and CO2 injection amount data of all historical time points in the previous time period can be preprocessed to obtain the downhole environment data and CO2 injection amount data that can characterize the entire time period and input into the working condition perception prediction model to predict the downhole environment data and CO2 injection amount data of the next time period. According to the predicted CO2 injection amount data of the next time period, a downlink control instruction for controlling the CO2 injection amount of each oil layer in the next time period can be generated.

[0053] In some embodiments, the downhole environmental data can also be input into a risk perception prediction model to predict risk perception data; the predicted operating condition perception data and operating condition thresholds are compared, and the risk perception data and risk thresholds are compared to generate a risk warning level; and pre-set response strategies and suggestions corresponding to the risk warning level are executed.

[0054] By combining the working condition perception prediction model and the risk perception prediction model, the risk level of the underground environment can be judged more objectively, and then a more reasonable risk warning level and corresponding risk response strategies and suggestions can be given.

[0055] The downhole environmental data at the current time point can be input into the risk perception prediction model to predict the risk perception data at the next time point. The predicted risk perception data at the next time point can be compared with the pre-set risk threshold, and the predicted downhole environmental data at the next time point can be compared with the working condition threshold to generate the risk warning level at the next time point. The downhole environmental data can include temperature data, pressure data, flow data and wellbore deformation data of the oil pipe, casing and annulus, and the working condition threshold can include multiple temperature thresholds, multiple pressure thresholds, multiple flow thresholds and multiple wellbore deformation thresholds. The downhole environmental data of the current time period can also be input into the risk perception prediction model to predict the risk perception data of the next time period. The predicted risk perception data of the next time period can be compared with the pre-set risk threshold, and the predicted downhole environmental data of the next time period can be compared with the working condition threshold to generate the risk warning level of the next time period. According to the generated risk warning level, the pre-set response strategies and suggestions corresponding to the risk warning level can be executed. For example, the pressure range required for actual operation is 200bar to 400bar. The first pressure threshold can be set to 190bar as the early warning point, and the second pressure threshold can be set to 410bar as the alarm point. When the predicted pressure data is less than or equal to the first pressure threshold, a downhole equipment self-check suggestion can be generated to detect whether there is a related downhole equipment failure that causes insufficient pressure. If there is a downhole equipment failure, stop the operation and repair the failure; if there is no downhole equipment failure, generate a pressurization suggestion instruction. When the predicted pressure data is greater than the first pressure threshold and less than the second pressure threshold, a normal operation suggestion is generated. When the predicted pressure data is greater than or equal to the second pressure threshold, a downhole equipment self-check suggestion is executed to detect whether the related downhole equipment fails or is damaged, and a decompression suggestion instruction is generated.

[0056] In some embodiments, auxiliary working condition perception and risk perception can also be performed based on the intrinsic connection between different data in the downhole environmental data, including establishing a temperature-pressure equation between temperature data and pressure data, establishing a temperature-flow equation between temperature data and flow data, and establishing a rheological equation between flow data and wellbore deformation data. For example, at the same temperature, as the CO2 injection pressure increases, the density and viscosity of the produced crude oil will decrease, so a temperature-pressure equation ρ=f(P,T) between temperature data and pressure data can be constructed, where P represents pressure, T represents temperature, and ρ can describe the change of a certain key flow parameter (such as density or viscosity) at a given temperature and pressure. By establishing the intrinsic connection between different data in the downhole environmental data, it is easier to understand how the intrinsic connection between different data in the downhole environmental data affects the output of crude oil and the changes in the downhole environment, thereby providing more comprehensive data support for the detailed characterization of the downhole environment and the early warning and response of risks.

[0057] S302: Encode the downlink control instruction to obtain downlink coded data.

[0058] In some embodiments, the downlink control instruction includes CO2 injection amount data of each oil layer in the well. The generated downlink control instruction can be encoded by using PPM coding, UWB coding or other coding technology to obtain downlink coded data. PPM coding can use different pulse positions to represent different binary data. UWB coding can use Gaussian single-cycle ultra-short-time pulses to carry information. For example, the generated downlink control instruction can be converted into a binary representation, and then the pulse signals at different positions are generated by PPM coding to represent the downlink control instruction, and then the downlink coded data can be obtained.

[0059] S303: Control the opening of the annular throttle valve according to the downlink coded data, so that the protective fluid in the wellbore annulus forms a downward pressure wave.

[0060] In some embodiments, a mapping relationship between coded data and opening size can be established, and the downlink coded data can be substituted into the established mapping relationship, thereby obtaining the downlink target opening of the annular throttle valve. The opening of the annular throttle valve can be adjusted to the downlink target opening, the flow rate of the annular protection fluid can be changed, and a downlink pressure wave propagating downward along the annulus can be generated. For example, the friction coefficient between the annular protection fluid and the tubing and casing, the elastic coefficient of the tubing and casing, and the elastic coefficient of the annular protection fluid can be comprehensively considered to establish a multivariate linear or nonlinear mapping relationship between the coded data and the opening size. The downlink coded data can be substituted into the established multivariate linear or nonlinear mapping relationship, and the downlink target opening sequence of the annular throttle valve corresponding to each downlink coded data can be obtained. The opening of the annular throttle valve can be continuously adjusted according to the obtained downlink target opening sequence, the flow rate of the annular protection fluid can be changed, and a downlink pressure wave propagating downward along the annulus can be generated.

[0061] For example, the downlink coded data has a plurality of bits, each of which has a bit value. The downlink coded data may be a bit value sequence formed by the plurality of bit values ​​in sequence. The opening of the annular throttle valve may be controlled according to each bit value in the bit value sequence and the timing of the bit values, so that the protective fluid in the annular space forms an upward pressure wave corresponding to the bit value sequence.

[0062] S304: Detect the downward pressure wave of the protection fluid in the wellbore annulus to obtain the downward control instruction.

[0063] In some embodiments, downhole sensors and downhole dispensers may be provided in each oil layer, and the downhole sensors in each oil layer may include pressure sensors. The pressure sensors in each oil layer may detect the downward pressure wave generated by adjusting the opening of the annular throttle valve, and may obtain downward detection data based on the downward pressure wave. The downward pressure wave may also be affected by various factors during the transmission process, such as environmental factors, equipment accuracy, human operation, etc., which may lead to slight deviations between the obtained downward detection data and the actual downward control instructions. The downhole dispensers in each oil layer may process the downward detection data by data processing methods such as filtering, data modeling, and data screening to obtain downward control instructions. For example, for downward detection data with normally distributed noise, a Gaussian low-pass filter may be used to process the upward detection data to obtain downward control instructions. For another example, the influence of factors such as the friction coefficient between the annulus protection fluid and the oil pipe and casing, the elastic coefficient of the wall of the oil pipe and casing, and the elastic coefficient of the annulus protection fluid on the uplink detection data can be considered, and a multivariate linear or nonlinear mapping relationship between the detection data and the coded data can be established. The downlink detection data can be substituted into the established multivariate linear or nonlinear mapping relationship to obtain the downlink control instructions.

[0064] For example, the ground controller can send the downhole environmental data to the signal analysis device. The signal analysis device can generate a downlink control instruction based on the downhole environmental data; the downlink control instruction can be sent to the ground encoder. The ground encoder can encode the downlink control instruction to obtain downlink coded data; the downlink coded data can be sent to the ground controller so that the ground controller can control the opening of the annular throttle valve according to the downlink coded data. Each of the above-mentioned downhole dispensers is provided with a downhole pressure sensor, a downhole encoder, and a downhole controller. The downhole pressure sensor can detect the downward pressure wave of the protective fluid in the wellbore annulus to obtain the downlink coded data. The downhole encoder can analyze the downlink encoder to obtain the downlink control instruction. The downhole controller can adjust the opening of the downhole dispenser according to the downlink control instruction to adjust the CO2 injection amount.

[0065] Optionally, the ground controller may send the downhole environment data and its corresponding dispenser identification information to the signal analysis device. The signal analysis device may generate a downlink control instruction based on the downhole environment data; the downlink control instruction and its corresponding dispenser identification information may be sent to the ground encoder. The ground encoder may encode the downlink control instruction and the dispenser identification information to obtain downlink encoded data; the downlink encoded data may be sent to the ground controller so that the ground controller controls the opening of the annular throttle valve according to the downlink encoded data.

[0066] Each of the above-mentioned downhole dispensers is provided with a downhole pressure sensor, a downhole encoder, and a downhole controller. The downhole pressure sensor on each downhole dispenser can detect the downward pressure wave of the protective fluid in the wellbore annulus to obtain the downward coded data. The downhole encoder on each downhole dispenser can parse the downward encoder to obtain the downward control instruction and its corresponding dispenser identification information. The downhole controller on each downhole dispenser can detect whether the dispenser identification information matches the downhole dispenser where it is located. If not, the downward control instruction can be ignored. If so, the opening of the downhole dispenser can be adjusted according to the downward control instruction to adjust the CO2 injection amount. In this way, the CO2 injection amount of each oil layer can be accurately adjusted.

[0067] S305: adjusting the opening of the downhole injector according to the downlink control instruction to adjust the CO2 injection amount of each oil layer.

[0068] In some embodiments, the downhole dispenser of each oil layer can obtain the CO2 injection amount corresponding to each oil layer according to the downlink control instruction. A mapping relationship between the CO2 injection amount and the opening size can be established, and the CO2 injection amount corresponding to each oil layer is substituted into the established mapping relationship, and then the injection target opening of the downhole dispenser of each oil layer can be obtained. The gas nozzle short section of the downhole dispenser of each oil layer can be adjusted to change the opening to the injection target opening, so as to realize the refined control of the CO2 injection amount of each oil layer at each time point or each time period.

[0069] In some embodiments, a database of downhole environmental data, CO2 injection volume data of each oil layer, and risk perception data can also be established; the database can be updated based on the downhole environmental data, CO2 injection volume data of each oil layer, and risk perception data; and the operating condition perception prediction model and the risk perception prediction model can be optimized based on the updated database.

[0070] By establishing a database of downhole environmental data, CO2 injection volume data for each oil layer, and risk perception data, and regularly optimizing the perception prediction model and risk perception prediction model, the accuracy and generalization ability of the perception prediction model and risk perception prediction model can be maintained, providing technical support for subsequent CO2 injection operations.

[0071] The downhole environmental data may include at least temperature data, pressure data, flow data and wellbore deformation data of the oil pipe, casing and annulus. Each set of historical downhole environmental data in the database corresponds to a set of historical CO2 injection amount data and historical risk perception data of each oil layer. The database can be updated according to the downhole environmental data, CO2 injection amount data and risk perception data of each oil layer during each CO2 injection amount adjustment process of each oil layer. For the updated database, the working condition perception prediction model and the risk perception prediction model can be regularly optimized using the updated database.

[0072] The optimization process of the working condition perception prediction model includes: according to the downhole environmental data and CO2 injection volume data in the continuous time points or time periods in the updated database, the trained working condition perception prediction model can be used to predict the downhole environmental data and CO2 injection volume data at the next time point or time period; the working condition perception prediction model can be adjusted by using the deviation between the predicted downhole environmental data and CO2 injection volume data and the measured downhole environmental data and CO2 injection volume data; when the performance index of the working condition perception prediction model reaches a certain threshold, the adjustment is ended, and the optimized working condition perception prediction model can be obtained.

[0073] The optimization process of the risk perception prediction model includes: according to the downhole environmental data at a time point in the updated database, the trained risk perception prediction model can be used to predict the risk perception data at the next time point; the risk perception prediction model can be adjusted by utilizing the deviation between the predicted risk perception data and the measured risk perception data; when the performance index of the risk perception prediction model reaches a certain threshold, the adjustment is terminated to obtain an optimized risk perception prediction model.

[0074] Based on the above-mentioned wireless measurement and adjustment method for injection wellbore, this specification also proposes an embodiment of a wireless measurement and adjustment device for injection wellbore. Figure 4 As shown, the evaluation device may specifically include the following modules:

[0075] The encoding module 401 may be used to encode the downhole environment data collected by the downhole sensor to obtain uplink encoded data;

[0076] The control module 402 can be used to control the opening of the annular throttle valve according to the uplink coded data, so that the protection fluid in the wellbore annulus forms an uplink pressure wave;

[0077] The detection module 403 can be used to detect the upward pressure wave of the protection fluid in the wellbore annulus to obtain upward detection data;

[0078] The analysis module 404 can be used to analyze the uplink detection data to obtain the downhole environment data.

[0079] In some embodiments, the control module 402 may be specifically used to inject CO2 into each oil layer; and obtain CO2 injection amount data during the CO2 injection process of each oil layer.

[0080] In some embodiments, the control module 402 can also be used to generate downlink control instructions according to the downhole environmental data; encode the downlink control instructions to obtain downlink coded data; control the opening of the annular throttle valve according to the downlink coded data so that the protective fluid in the wellbore annulus forms a downward pressure wave; detect the downward pressure wave of the protective fluid in the wellbore annulus to obtain the control instructions; adjust the opening of the downhole dispenser according to the control instructions to adjust the CO2 injection amount of each oil layer.

[0081] In some embodiments, the control module 402 may also be used to obtain historical downhole environmental data, historical CO2 injection volume data of each oil layer, and historical risk perception data; based on the historical downhole environmental data and the historical CO2 injection volume data of each oil layer, a working condition perception prediction model is constructed;

[0082] In some embodiments, the control module 402 may also be specifically used to input the downhole environment data and the CO2 injection amount data of each oil layer into a working condition perception prediction model to predict working condition perception data; and generate downlink control instructions based on the predicted working condition perception data.

[0083] In some embodiments, the above-mentioned control module 402 can also be specifically used to input the downhole environmental data into the risk perception prediction model to predict the risk perception data; compare the predicted working condition perception data with the working condition threshold, and compare the risk perception data with the risk threshold to generate a risk warning level; and execute pre-set response strategies and suggestions corresponding to the risk warning level.

[0084] In some embodiments, the above-mentioned control module 402 can also be specifically used to establish a database of downhole environmental data, CO2 injection volume data of each oil layer and risk perception data; update the database according to the downhole environmental data, CO2 injection volume data of each oil layer and risk perception data; and optimize the operating condition perception prediction model and the risk perception prediction model based on the updated database.

[0085] It should be noted that the units, devices or modules described in the above embodiments can be implemented by computer chips or entities, or by products with certain functions. For the convenience of description, the above devices are described separately by functions divided into various modules. Of course, when implementing this specification, the functions of each module can be implemented in the same or more software and / or hardware, or the modules that implement the same function can be implemented by a combination of multiple sub-modules or sub-units. The device embodiments described above are only schematic. For example, the division of the units is only a logical function division. There may be other division methods in actual implementation, such as multiple units or components can be combined or integrated into another system, or some features can be ignored or not executed. Another point is that the mutual coupling or direct coupling or communication connection shown or discussed can be through some interfaces, indirect coupling or communication connection of devices or units, which can be electrical, mechanical or other forms.

[0086] It can be seen from the above that a wireless measurement and adjustment device for injection wellbore provided in the embodiment of this specification can better transmit pressure wave signals, thereby improving the precision of wireless measurement and adjustment of CO2 injection amount in each oil layer in the CO2 injection well scenario, which is of great significance for improving the transmission effect of pressure wave signals in the CO2 injection well scenario and wireless measurement and adjustment and risk identification of CO2 injection wells.

[0087] The embodiments of the present specification also provide a computer device equipped with a wellbore wireless measurement and adjustment method, including a processor and a memory for storing instructions executable by the processor. When the processor is implemented, it can perform the following steps according to the instructions: encode the downhole environmental data collected by the downhole sensor to obtain uplink coded data; control the opening of the annular throttle valve according to the uplink coded data so that the protective fluid in the annulus forms an upward pressure wave; detect the upward pressure wave of the protective fluid in the annulus to obtain the uplink coded data; and parse the uplink coded data to obtain the downhole environmental data.

[0088] In order to complete the above instructions more accurately, refer to Figure 5 As shown, the embodiment of this specification also provides another specific electronic device, wherein the electronic device includes a network communication port 501, a processor 502 and a memory 503, and the above structures are connected through internal cables so that each structure can perform specific data interaction.

[0089] The network communication port 501 can be used to control the opening of the annular throttle valve according to the uplink coded data, so that the protective fluid in the annular space forms an uplink pressure wave.

[0090] The processor 502 can be specifically used to encode the downhole environmental data collected by the downhole sensor to obtain uplink encoded data; detect the uplink pressure wave of the protective fluid in the annulus to obtain uplink encoded data; and analyze the uplink encoded data to obtain the downhole environmental data.

[0091] The memory 503 may be specifically used to store corresponding instruction programs.

[0092] In this embodiment, the network communication port 1101 can be a virtual port that is bound to different communication protocols so that different data can be sent or received. For example, the network communication port can be a port responsible for web data communication, a port responsible for FTP data communication, or a port responsible for email data communication. In addition, the network communication port can also be a physical communication interface or communication chip. For example, it can be a wireless mobile network communication chip, such as GSM, CDMA, etc.; it can also be a Wifi chip; it can also be a Bluetooth chip.

[0093] In this embodiment, the processor 1102 may be implemented in any appropriate manner. For example, the processor may take the form of a microprocessor or processor and a computer-readable medium storing a computer-readable program code (such as software or firmware) executable by the (micro)processor, a logic gate, a switch, an application specific integrated circuit (ASIC), a programmable logic controller, and an embedded microcontroller, etc. This specification does not limit this.

[0094] In this embodiment, the memory 1103 may include multiple levels. In a digital system, anything that can store binary data can be a memory; in an integrated circuit, a circuit with a storage function that has no physical form is also called a memory, such as RAM, FIFO, etc.; in a system, a storage device with a physical form is also called a memory, such as a memory stick, TF card, etc.

[0095] Those skilled in the art will appreciate that embodiments of the present invention may be provided as methods, systems, or computer program products. Therefore, the present invention may take the form of a complete hardware embodiment, a complete software embodiment, or an embodiment combining software and hardware. Moreover, the present invention may take the form of a computer program product implemented 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.

[0096] The present invention is described with reference to flowcharts and / or block diagrams of methods, devices (systems), and computer program products according to embodiments of the present invention. It should be understood that each process and / or block in the flowchart and / or block diagram, as well as the combination of processes and / or blocks in the flowchart and / or block diagram, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing device to produce a machine, so that the instructions executed by the processor of the computer or other programmable data processing device generate instructions for implementing the processes in the flowchart and / or block diagram. Figure 1 A process or multiple processes and / or boxes Figure 1 A device that provides the functions specified in a block or multiple blocks.

[0097] These computer program instructions may also be stored in a computer-readable memory capable of directing a computer or other programmable data processing device to operate in a specific manner, so that the instructions stored in the computer-readable memory produce an article of manufacture comprising an instruction device, which implements the process Figure 1 A process or multiple processes and / or boxes Figure 1 A function specified in one or more boxes.

[0098] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operating steps are executed on the computer or other programmable device to produce a computer-implemented process, thereby providing instructions for implementing the process in the computer or other programmable device. Figure 1 A process or multiple processes and / or boxes Figure 1 The steps for the functions specified in one or more boxes.

[0099] The specific embodiments described above further illustrate the objectives, technical solutions and beneficial effects of the present invention in detail. It should be understood that the above description is only a specific embodiment of the present invention and is not intended to limit the scope of protection of the present invention. Any modifications, equivalent substitutions, improvements, etc. made within the spirit and principles of the present invention should be included in the scope of protection of the present invention.

Claims

1. A wireless measurement and adjustment method for injection wellbore, characterized in that: include: Encoding the downhole environment data collected by the downhole sensor to obtain uplink encoded data; The opening of the annular throttle valve is controlled according to the upward coded data, so that the protective fluid in the annular space forms an upward pressure wave; Detect the upward pressure wave of the protection fluid in the annulus and obtain the upward coded data; The uplink coded data is parsed to obtain the downhole environment data.

2. The method according to claim 1, characterized in that: Before encoding the downhole environment data collected by the downhole sensor to obtain uplink coded data, the method further includes: Injecting CO2 into each oil layer; The CO2 injection amount data during the CO2 injection process of each oil layer is obtained.

3. The method according to claim 1, characterized in that: The downhole environmental data at least includes temperature data, pressure data, flow data of the oil pipe and the annulus, and well wall deformation data.

4. The method according to claim 1, characterized in that: Also includes: generating a downlink control instruction according to the downhole environment data; Encoding the downlink control instruction to obtain downlink coded data; The opening of the annular throttle valve is controlled according to the downlink coded data, so that the protection fluid in the wellbore annulus forms a downward pressure wave; Detecting the downward pressure wave of the protection fluid in the wellbore annulus to obtain the downward control instruction; The opening of the downhole injector is adjusted according to the downlink control instruction to adjust the CO2 injection amount of each oil layer.

5. The method according to claim 4, characterized in that: Before generating the downlink control instruction according to the downhole environment data, the method further includes: Obtain historical downhole environmental data, historical CO2 injection volume data for each oil layer, and historical risk perception data; Based on the historical downhole environmental data and the historical CO2 injection volume data of each oil layer, a working condition perception prediction model is constructed; Based on the historical underground environment data and the historical risk perception data, a risk perception prediction model is constructed.

6. The method according to claim 5, characterized in that: The generating of the downlink control instruction according to the downhole environment data comprises: Inputting the downhole environment data and the CO2 injection amount data of each oil layer into the working condition perception prediction model to predict the working condition perception data; Generate a downlink control instruction based on the predicted working condition perception data.

7. The method according to claim 5, characterized in that: Also includes: Inputting the downhole environment data into a risk perception prediction model to predict risk perception data; Comparing the predicted operating condition perception data with the operating condition threshold, and comparing the risk perception data with the risk threshold, to generate a risk warning level; Execute pre-set response strategies and suggestions corresponding to risk warning levels.

8. The method according to claim 4, characterized in that: Also includes: Establish a database of downhole environmental data, CO2 injection volume data for each oil layer, and risk perception data; updating the database according to the downhole environment data, CO2 injection amount data of each oil layer and risk perception data; Based on the updated database, the operating condition perception prediction model and the risk perception prediction model are optimized.

9. A wireless measurement and adjustment device for injection wellbore, characterized in that: The device comprises: The encoding module is used to encode the downhole environment data collected by the downhole sensor to obtain uplink encoded data; A control module, used for controlling the opening of the annular throttle valve according to the upward coded data, so that the protection fluid in the wellbore annulus forms an upward pressure wave; A detection module is used to detect the upward pressure wave of the protection fluid in the wellbore annulus and obtain upward detection data; The analysis module is used to analyze the uplink detection data to obtain the downhole environment data.

10. A computer device comprising a memory, a processor and a computer program stored in the memory and executable on the processor, characterized in that: When the processor executes the computer program, the method according to any one of claims 1 to 8 is implemented.

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