Natural gas fracturing flowback fluid balance control system based on adaptive flow regulation

Abstract

The present application provides a natural gas fracturing flowback balance control system based on adaptive flow regulation, which relates to the technical field of flowback balance control, including: a natural gas fracturing control parameter receiving module, which receives natural gas fracturing control parameters; a flowback flow prediction timing information acquisition module, which performs flowback flow prediction and obtains flowback flow prediction timing information; a flowback flow monitoring timing information acquisition module, which obtains flowback flow monitoring timing information when natural gas fracturing starts; and a balance signal generation module, which generates a balance signal when the flowback flow prediction timing information is consistent with the flowback flow monitoring timing information. The present application can solve the technical problem that the accuracy of flow prediction and the real-time adjustment capability of the operation are poor in the prior art due to the fact that most of the flowback flow is estimated based on historical experience, so as to achieve the technical effect of improving the accuracy of flowback flow prediction and the real-time adjustment capability, and improving the efficiency and stability of fracturing operations.

Description

Technical Field

[0001] The present application relates to the technical field of flowback fluid balance control, and in particular to a natural gas fracturing flowback fluid balance control system based on adaptive flow regulation. Background Art

[0002] With the continuous development of natural gas resources, fracturing technology has played an important role in increasing oil and gas production. Especially in the exploitation of unconventional natural gas, hydraulic fracturing technology has been widely used.

[0003] At present, in existing fracturing operations, the prediction of flowback fluid flow mainly relies on empirical models based on historical data or simple mathematical formulas. Although these methods can provide a preliminary estimate of the flow rate to a certain extent, due to the large number of variables in the actual fracturing process, such as the type of fracturing fluid, the amount of fracturing fluid, the construction pressure, the duration of fracturing, and underground geological conditions, these traditional methods often cannot accurately reflect the complex geological environment and actual operating conditions, resulting in a large deviation between the predicted results and the actual flowback fluid flow. For example, the fracture diversion effect under certain geological conditions may be different from the conventional assumptions, and the flow of fracturing fluid may fluctuate greatly, which makes the prediction accuracy based on static or simplified models low. In addition, the existing models are also insufficient in adaptability and real-time performance. In different fracturing scenarios, the model parameters need to be adjusted in real time according to the actual data, but the existing technology often lacks this adaptive ability, resulting in the inability to make accurate adjustments in a short time.

[0004] In summary, the existing technology relies on historical experience to estimate the flowback fluid flow rate, which makes it difficult to fully consider the complex variables in the actual fracturing process, resulting in a large deviation between the predicted result and the actual flowback fluid flow rate, further affecting the accuracy of the flow prediction and the real-time adjustment capability of the operation, making it impossible for the parameter adjustment in the fracturing operation to quickly respond to field changes, reducing the operation efficiency, and may lead to technical problems such as waste of resources or instability of the fracturing effect. Summary of the invention

[0005] The purpose of this application is to provide a natural gas fracturing return fluid balance control system based on adaptive flow regulation, so as to solve the technical problems in the prior art that most of the return fluid flow is estimated based on historical experience, and it is difficult to fully consider the complex variables in the actual fracturing process, resulting in a large deviation between the predicted result and the actual return fluid flow, which further affects the accuracy of flow prediction and the real-time adjustment capability of the operation, making it impossible for parameter adjustment in the fracturing operation to respond quickly to field changes, reducing operation efficiency, and may cause waste of resources or instability of fracturing effect.

[0006] In view of the above problems, the present application provides a natural gas fracturing return fluid balance control system based on adaptive flow regulation, including: a natural gas fracturing control parameter receiving module, the natural gas fracturing control parameter receiving module is used to receive natural gas fracturing control parameters, wherein the natural gas fracturing control parameters include fracturing fluid dosage, construction pressure, fracturing time, fracturing scenario parameters, and fracturing fluid type; a return fluid flow prediction timing information acquisition module, the return fluid flow prediction timing information acquisition module is used to predict the return fluid flow according to the fracturing fluid dosage, the construction pressure, the fracturing time, the fracturing scenario parameters, and the fracturing fluid type, and obtain the return fluid flow prediction timing information; a return fluid flow monitoring timing information acquisition module, the return fluid flow monitoring timing information acquisition module is used to obtain the return fluid flow monitoring timing information when the natural gas fracturing starts; a balance signal generating module, the balance signal generating module is used to generate a balance signal when the return fluid flow prediction timing information is consistent with the return fluid flow monitoring timing information, and send it to the user end.

[0007] The technical solution provided in this application has at least the following technical effects or advantages:

[0008] By receiving natural gas fracturing control parameters, wherein the natural gas fracturing control parameters include fracturing fluid dosage, construction pressure, fracturing time, fracturing scenario parameters, and fracturing fluid type; predicting the flowback fluid flow rate according to the fracturing fluid dosage, the construction pressure, the fracturing time, the fracturing scenario parameters, and the fracturing fluid type, and obtaining the flowback fluid flow prediction timing information; when the natural gas fracturing starts, obtaining the flowback fluid flow monitoring timing information; when the flowback fluid flow prediction timing information is consistent with the flowback fluid flow monitoring timing information, generating a balance signal and sending it to the user end, that is, by achieving the technical goal of natural gas fracturing flowback fluid balance control based on adaptive flow regulation, and then dynamically adjusting the flow prediction, ensuring that the prediction result is more in line with the actual situation, achieving the technical effect of improving the flowback fluid flow prediction accuracy and real-time adjustment capability, thereby optimizing the operation parameters and improving the efficiency and stability of the fracturing operation.

[0009] The above description is only an overview of the technical solution of the present application. In order to more clearly understand the technical means of the present application, it can be implemented according to the contents of the specification, and in order to make the above and other purposes, features and advantages of the present application more obvious and easy to understand, the specific implementation methods of the present application are specifically cited below. It should be understood that the content described in this section is not intended to identify the key or important features of the embodiments of the present application, nor is it intended to limit the scope of the present application. Other features of the present application will become easy to understand through the following description. BRIEF DESCRIPTION OF THE DRAWINGS

[0010] In order to more clearly illustrate the technical solutions in the present application or the prior art, the drawings required for use in the embodiments or the description of the prior art will be briefly introduced below. Obviously, the drawings in the following description are only exemplary, and for ordinary technicians in this field, other drawings can be obtained based on the provided drawings without paying any creative work.

[0011] Figure 1 This is a schematic diagram of the structure of a natural gas fracturing flowback fluid balance control system based on adaptive flow regulation in this application;

[0012] Figure 2 This is a schematic diagram of the process of obtaining the predicted timing information of the flowback fluid in the natural gas fracturing flowback fluid balance control system based on adaptive flow regulation in this application.

[0013] Description of reference numerals:

[0014] A natural gas fracturing control parameter receiving module 11, a flowback fluid flow prediction time series information obtaining module 12, a flowback fluid flow monitoring time series information obtaining module 13, and a balance signal generating module 14. DETAILED DESCRIPTION

[0015] This application provides a natural gas fracturing flowback balance control system based on adaptive flow regulation, which solves the problem in the prior art that most of the flowback flow is estimated based on historical experience, and it is difficult to fully consider the complex variables in the actual fracturing process, resulting in a large deviation between the predicted result and the actual flowback flow, which further affects the accuracy of flow prediction and the real-time adjustment capability of the operation, making it impossible for parameter adjustment in the fracturing operation to respond quickly to field changes, reducing operation efficiency, and possibly causing resource waste or instability in the fracturing effect. The technical goal of natural gas fracturing flowback balance control based on adaptive flow regulation is achieved, and then the flow prediction is dynamically adjusted to ensure that the prediction result is more in line with the actual situation, so as to improve the accuracy of flowback flow prediction and real-time adjustment capability, thereby optimizing operation parameters and improving the efficiency and stability of fracturing operations.

[0016] Below, the technical solutions in the present application will be clearly and completely described with reference to the accompanying drawings. Obviously, the described embodiments are only part of the embodiments of the present application, rather than all of the embodiments of the present application. It should be understood that the present application is not limited to the example embodiments described herein. Based on the embodiments of the present application, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of the present application. It should also be noted that, for the convenience of description, only the parts related to the present application are shown in the accompanying drawings, rather than all of them.

[0017] Please refer to the attached Figure 1The present application provides a natural gas fracturing flowback fluid balance control system based on adaptive flow regulation, specifically including:

[0018] The natural gas fracturing control parameter receiving module 11 is used to receive natural gas fracturing control parameters, wherein the natural gas fracturing control parameters include fracturing fluid dosage, construction pressure, fracturing time, fracturing scenario parameters, and fracturing fluid type.

[0019] Specifically, during the natural gas fracturing process, relevant fracturing control parameters are received, including fracturing fluid dosage, construction pressure, fracturing time, fracturing scenario parameters, and fracturing fluid type. Fracturing fluid dosage refers to the volume of liquid injected into the ground during the fracturing process. Construction pressure refers to the pressure required to be maintained during the fracturing process. The higher the construction pressure, the more fracturing fluid is needed to maintain the effect. Fracturing time refers to the time required to complete the entire fracturing operation. The longer the fracturing time, the greater the possibility of crack generation. Fracturing scenario parameters are used to describe specific fracturing formations or environmental conditions, such as the permeability or porosity of the formation. Fracturing fluid type is the specific type of liquid selected for fracturing operations, such as linear gel or cross-linked gel. Different types of fracturing fluids are suitable for different formation conditions or operation requirements. Linear gel may be more suitable for low-permeability formations, while cross-linked gel may be more effective for high-stress formations. By coordinating and optimizing natural gas fracturing control parameters, precise control of fracturing operations can be achieved, thereby providing a stable basis for the balanced regulation of return fluids.

[0020] The flowback fluid flow prediction timing information acquisition module 12 is used to predict the flowback fluid flow according to the fracturing fluid dosage, the construction pressure, the fracturing time, the fracturing scenario parameters, and the fracturing fluid type, and obtain the flowback fluid flow prediction timing information.

[0021] Specifically, the prediction of the flowback fluid flow is based on multiple key parameters. The amount of fracturing fluid determines the total amount of liquid injected into the formation. The greater the amount of fracturing fluid injected, the wider the cracks in the formation may expand, and the greater the flowback fluid flow may be, and vice versa. The higher the construction pressure, the more cracks will be formed, which will affect the flow of the flowback fluid, resulting in more liquid backflow, and vice versa. The longer the fracturing time, the deeper the liquid penetrates underground, which in turn brings more flowback fluid, and vice versa. The greater the fracturing scenario parameters, such as the permeability and porosity of the formation, the higher the flowback fluid flow, and vice versa. The type of fracturing fluid will also affect the flowback fluid flow. For example, linear glue has a higher flowback fluid flow due to its better fluidity, while cross-linked glue has a lower flowback fluid flow due to its higher viscosity. Through the flowback fluid flow prediction, the changes in the flowback fluid flow marked in chronological order are obtained as the flowback fluid flow prediction time series information.

[0022] The flowback fluid flow monitoring timing information acquisition module 13 is used to obtain the flowback fluid flow monitoring timing information when the natural gas fracturing starts.

[0023] Specifically, when natural gas fracturing begins, the flowback fluid flow monitoring time series information will be collected and recorded in real time, including the flow data of the flowback fluid at different time points. For example, in the first hour after the start of fracturing, the flowback fluid flow rate was measured to be 20 cubic meters per hour, and after two hours, the flow rate may rise to 40 cubic meters per hour, reflecting that with the deepening of the fracturing operation, the expansion of the cracks and the increase of liquid penetration, the flowback fluid flow rate gradually increases. Real-time acquisition of flowback fluid flow monitoring time series information helps to understand the dynamic changes in the fracturing process and provide trends in liquid flow, thereby guiding subsequent operational decisions and optimizing the treatment process of the flowback fluid.

[0024] The balance signal generating module 14 is used to generate a balance signal and send it to the user end when the backflow liquid flow prediction timing information is consistent with the backflow liquid flow monitoring timing information.

[0025] Specifically, when the flowback fluid flow prediction timing information is consistent with the flowback fluid flow monitoring timing information, it means that the flowback fluid flow data obtained by the prediction model is close to the actual monitoring data, and there is no significant difference between the two, indicating that the prediction is consistent with the actual situation, and then a balance signal is generated. The balance signal is a confirmation of the consistency between the predicted data and the actual monitoring data, which means that there are no abnormalities in the parameter setting and flow prediction of the current fracturing operation, indicating that the flowback fluid flow changes in the actual operation process are accurately reflected, the system is working normally, and the balance between the prediction and the actual operation is maintained. The generated balance signal will then be sent to the user end, and the balance signal will be passed to the operator or manager, who can know the accuracy of the prediction model in time and that the current operation parameter settings are appropriate. For example, the user end receives a notification prompting that the prediction has been successfully predicted and is consistent with the monitoring data, and can continue to operate according to the current operation parameters.

[0026] The natural gas fracturing return fluid balance control system based on adaptive flow regulation can achieve the technical goal of natural gas fracturing return fluid balance control based on adaptive flow regulation, and then dynamically adjust the flow prediction to ensure that the prediction result is more in line with the actual situation, thereby achieving the technical effect of improving the accuracy of return fluid flow prediction and real-time adjustment capability, thereby optimizing operation parameters and improving the efficiency and stability of fracturing operations.

[0027] Further, if Figure 2 As shown, this application also includes:

[0028] A first constraint condition is constructed according to the fracturing fluid dosage, the construction pressure, the fracturing duration, and the fracturing scenario parameters; a second constraint condition is constructed according to the fracturing fluid type; natural gas fracturing normal samples are collected based on the first constraint condition and the second constraint condition to obtain a natural gas fracturing sample set; wherein the natural gas fracturing sample set has a backflow fluid flow record time series label set; a mode analysis is performed on the backflow fluid flow record time series label set to obtain the backflow fluid flow prediction time series information.

[0029] Specifically, the first constraint condition is constructed based on the amount of fracturing fluid, construction pressure, fracturing time and fracturing scenario parameters. The amount of fracturing fluid determines the total amount of liquid injected into the formation. The larger the fracturing fluid, the greater the construction pressure, and the larger the cracks formed, and vice versa. The fracturing time affects the extension of the cracks. The combination of fracturing fluid amount, construction pressure, fracturing time, and fracturing scenario parameters together constitutes the basic conditions and restrictions of the fracturing operation, and the first constraint condition is constructed.

[0030] Secondly, the second constraint condition is constructed based on the type of fracturing fluid. Different types of fracturing fluids have different performances, and the constraint requirements of their application scenarios are also different. Therefore, the optimal choice needs to be determined based on the characteristics of the formation. For example, linear glue is suitable for low-permeability formations due to its low viscosity, while cross-linked glue improves its support capacity for fractures through higher viscosity.

[0031] After constructing the first and second constraints, we collect samples of natural gas fracturing without abnormalities, and screen the natural gas fracturing samples that meet the constraints, so as to integrate and obtain a collection of natural gas fracturing samples. By recording and sorting out various parameters and results in actual construction, such as the formation of cracks under different fracturing fluid dosages and pressure conditions, we can screen out sample data that meet the normal fracturing mode to ensure the accuracy of the analysis.

[0032] The obtained natural gas fracturing sample set also includes a set of time series labels for the flowback flow rate. The flowback flow rate record time series label set marks the change of the flowback flow rate in chronological order. For example, the flowback flow rate is 30 cubic meters per hour one hour after construction, and drops to 20 cubic meters per hour two hours later, thereby analyzing the dynamic characteristics of the flowback fluid.

[0033] Finally, the mode analysis of the return flow record time series label set is performed to obtain the return flow prediction time series information. Mode analysis is to extract the flow records with the most occurrences. For example, if the majority of the return flow record time series labels in multiple sets of data show that the flow is stable at 20 cubic meters per hour, then the flow can be predicted as a characteristic flow, providing guidance for subsequent operations.

[0034] By constructing dual constraints based on fracturing fluid dosage, construction pressure, fracturing duration, scenario parameters and liquid type, the natural gas fracturing sample set is effectively screened and analyzed in combination with the time series labels of the return fluid flow. The flow prediction time series information finally obtained can not only optimize the fracturing operation, but also provide an important basis for the balance adjustment of the return fluid.

[0035] Furthermore, the present application also includes:

[0036] Based on the first constraint condition and the second constraint condition, natural gas fracturing samples without abnormality are collected to obtain a first-level natural gas fracturing sample set, wherein any first-level natural gas fracturing sample has a fracturing fluid dosage label, a construction pressure label, a fracturing duration label, and a fracturing scenario parameter label; a third constraint condition is constructed according to the fracturing fluid dosage label, the construction pressure label, the fracturing duration label, and the fracturing scenario parameter label; based on the second constraint condition and the third constraint condition, natural gas fracturing samples without abnormality are collected to obtain a second-level natural gas fracturing sample set; loop analysis is performed until an N-level natural gas fracturing sample set is obtained; the first-level natural gas fracturing sample set, the second-level natural gas fracturing sample set, and the N-level natural gas fracturing sample set are added to the natural gas fracturing sample set.

[0037] Specifically, based on the first constraint and the second constraint, samples without differences are collected, such as obtaining the first-level natural gas fracturing samples whose fracturing fluid type label satisfies the second constraint, and whose fracturing fluid dosage label, construction pressure label, fracturing duration label, and fracturing scenario parameter label satisfy the first constraint, thereby integrating and obtaining the first-level natural gas fracturing sample set. Any first-level natural gas fracturing sample in the first-level natural gas fracturing sample set has the fracturing fluid dosage label, construction pressure label, fracturing duration label, and fracturing scenario parameter label.

[0038] Next, the third constraint is further constructed based on the fracturing fluid dosage label, construction pressure label, fracturing duration label, and fracturing scenario parameter label in the first-level natural gas fracturing sample. The third constraint is a supplement and refinement of the first and second constraints, such as specifying the fracturing fluid dosage range, construction pressure range, fracturing duration, and fracturing scenario parameters. This refinement of the constraint helps to screen samples more accurately.

[0039] Then, based on the second and third constraints, continue to collect samples that meet the conditions, so as to obtain a secondary natural gas fracturing sample set. For example, the natural gas fracturing samples in the primary natural gas fracturing sample set can be screened and evolved into high-pressure natural gas fracturing samples by the third constraint.

[0040] Afterwards, the second-level natural gas fracturing sample set is iteratively analyzed and screened according to the higher-level constraints, and the analysis is gradually cyclical, and finally an N-level natural gas fracturing sample set is formed. With the iteration of the cycle, the characteristic range of the natural gas fracturing samples is clearer. For example, in the third-level natural gas fracturing sample set, the fracturing fluid type is further limited to cross-linked glue, or the construction time is extended to 90 minutes.

[0041] Finally, all natural gas fracturing sample sets from the first-level natural gas fracturing sample set to the N-level natural gas fracturing sample set are unified and added to the final natural gas fracturing sample set, which includes all the identical samples optimized and screened step by step, providing reliable and comprehensive data support for subsequent analysis and prediction.

[0042] Through cyclic analysis based on constraints at different levels, the screening process of natural gas fracturing samples can be gradually refined, which not only enhances the targetedness of the samples, but also ensures that the samples screened under complex conditions are highly applicable and accurate, providing a solid data foundation for natural gas fracturing operations.

[0043] Furthermore, the present application also includes:

[0044] Obtain a candidate natural gas fracturing sample with no anomaly, wherein the candidate natural gas fracturing sample with no anomaly has a candidate fracturing fluid type label, a candidate fracturing fluid dosage label, a candidate construction pressure label, a candidate fracturing duration label, and a candidate fracturing scenario parameter label; when the candidate fracturing fluid type label satisfies the second constraint condition, and the candidate fracturing fluid dosage label, the candidate construction pressure label, the candidate fracturing duration label, and the candidate fracturing scenario parameter label meet the first constraint condition, add the candidate natural gas fracturing sample with no anomaly to the first-level natural gas fracturing sample set.

[0045] Specifically, in the screening of natural gas fracturing samples, the selected natural gas fracturing samples without abnormality are obtained. The key features of the selected natural gas fracturing samples without abnormality include the selected fracturing fluid type label, the selected fracturing fluid dosage label, the selected construction pressure label, the selected fracturing time label and the selected fracturing scenario parameter label. These labels fully describe the basic properties of each sample. For example, the fracturing fluid type of a selected sample is linear gel, the fracturing fluid dosage is 500 cubic meters, the construction pressure is 50 MPa, the fracturing time is 30 minutes, and the formation permeability in the fracturing scenario parameters is 0.02 Darcy and the porosity is 12%.

[0046] Next, determine whether the candidate fracturing fluid type label meets the preset second constraint. If the candidate fracturing fluid type label meets the second constraint, such as selecting a cross-linked adhesive to adapt to high-stress formations, the basic requirements of the liquid type are met. At the same time, the candidate fracturing fluid dosage label, the candidate construction pressure label, the candidate fracturing duration label, and the candidate fracturing scenario parameter label need to jointly meet the first constraint. When all labels of the candidate natural gas fracturing no abnormal sample meet the above conditions, the candidate natural gas fracturing no abnormal sample is added to the first-level natural gas fracturing sample set, and qualified samples are gathered for analysis of specific scenarios.

[0047] By screening various labels of the selected samples under constraints, the homogeneous samples that meet the requirements of natural gas fracturing operations can be effectively selected, ensuring that the first-level natural gas fracturing sample set provides reliable data support for subsequent analysis and prediction.

[0048] Furthermore, the present application also includes:

[0049] When the to-be-selected fracturing fluid type label is the same as the fracturing fluid type, the to-be-selected fracturing fluid type label is deemed to satisfy the second constraint condition; when the first deviation between the to-be-selected fracturing fluid usage label and the fracturing fluid usage is less than or equal to the first deviation threshold, and the second deviation between the to-be-selected construction pressure label and the construction pressure is less than or equal to the second deviation threshold, and the third deviation between the to-be-selected fracturing duration label and the fracturing duration is less than or equal to the third deviation threshold, and the fourth deviation between the to-be-selected fracturing scenario parameter label and the fracturing scenario is less than or equal to the fourth deviation threshold, the to-be-selected fracturing fluid usage label, the to-be-selected construction pressure label, the to-be-selected fracturing duration label, and the to-be-selected fracturing scenario parameter label are deemed to satisfy the first constraint condition.

[0050] Specifically, when the candidate fracturing fluid type label is the same as the fracturing fluid type in the natural gas fracturing control parameters, the candidate fracturing fluid type label is considered to meet the second constraint. For example, if the fracturing fluid type of the current operation is the same as the linear gel, and the fracturing fluid type of the candidate fracturing fluid type label is also a linear gel, then the candidate fracturing fluid type label is considered to meet the second constraint. Different types of fracturing fluids differ in permeability, support, and fluidity. Only by ensuring that the selected liquid type meets the operation requirements can the fracturing effect be guaranteed.

[0051] The deviation between the to-be-selected fracturing fluid dosage label and the fracturing fluid dosage is taken as the first deviation. When the first deviation between the to-be-selected fracturing fluid dosage label and the fracturing fluid dosage is less than or equal to the first deviation threshold, it indicates that the to-be-selected fracturing fluid dosage label is very close to the set dosage. For example, if the set fracturing fluid dosage is 1,000 cubic meters, and the dosage of the to-be-selected sample is 900 cubic meters or 1,100 cubic meters, then its deviation is within a certain threshold range and is deemed to meet the conditions. At the same time, when the deviation between the to-be-selected construction pressure label and the construction pressure in the natural gas fracturing control parameter, that is, the second deviation is less than or equal to the second deviation threshold, it indicates that the pressure of the to-be-selected natural gas fracturing normal sample is close to the pressure of the current fracturing operation. At the same time, the third deviation between the to-be-selected fracturing duration label and the fracturing duration in the natural gas fracturing control parameter is less than or equal to the third deviation threshold, indicating that the fracturing duration of the to-be-selected natural gas fracturing normal sample is close to the set time. At the same time, the fourth deviation of the fracturing scenario parameter label to be selected and the fracturing scenario in the natural gas fracturing control parameter is less than or equal to the fourth deviation threshold, indicating that the formation parameters of the sample to be selected, such as permeability and porosity, are close to the set formation conditions, and it is considered that the fracturing fluid dosage label to be selected, the construction pressure label to be selected, the fracturing duration label to be selected, and the fracturing scenario parameter label to be selected meet the first constraint condition, ensuring that the sample to be selected for natural gas fracturing is consistent with the operation requirements in terms of various key parameters, and ensuring the effectiveness of the fracturing operation. Among them, the first deviation threshold, the second deviation threshold, the third deviation threshold and the fourth deviation threshold are obtained by technicians in this field by custom settings according to actual conditions.

[0052] By setting multiple deviation thresholds and comparing the differences between each parameter of the candidate sample and the set parameters one by one, the qualified samples can be effectively screened out, ensuring the quality and applicability of the candidate natural gas fracturing samples, thereby providing a reliable basis for fracturing operations.

[0053] Furthermore, the present application also includes:

[0054] The start time of the return fluid flow monitoring timing information is aligned with the start time of the return fluid flow prediction timing information, and the return fluid flow prediction timing information is intercepted to obtain the return fluid intercepted flow prediction timing information; the return fluid flow deviation timing information of the return fluid intercepted flow prediction timing information and the return fluid flow monitoring timing information is counted; the proportion of the time when the return fluid flow deviation in the return fluid flow deviation timing information is greater than or equal to the return fluid flow deviation threshold is counted, and is set as the return fluid flow abnormality; when the return fluid flow abnormality is greater than or equal to the abnormality threshold, it is regarded that the return fluid flow prediction timing information is inconsistent with the return fluid flow monitoring timing information; otherwise, the return fluid flow prediction timing information is regarded as consistent with the return fluid flow monitoring timing information.

[0055] Specifically, align the start time of the backflow flow monitoring time series information with the backflow flow prediction time series information to ensure that the two time series information are compared from the same time point. For example, if the start time of the backflow flow monitoring data is 9:00 a.m. and the start time of the prediction time series information is 9:15 a.m., then the prediction time series information needs to be adjusted to start at 9:00 a.m. to ensure time synchronization. After alignment, intercept the backflow flow prediction time series information to ensure that its duration is the same as the monitoring time series information, and obtain the prediction data for the time period consistent with the actual monitoring data.

[0056] Next, the flow deviation timing information between the flow interception flow prediction timing information and the flow monitoring timing information is statistically analyzed, and the flow deviation at each time point can be obtained by calculating the difference between the monitored flow and the predicted flow at each corresponding moment.

[0057] Subsequently, the number of moments in which the flowback flow deviation in the flowback flow deviation time series information is greater than or equal to the flowback flow deviation threshold is counted, and the ratio of the number of moments to the total moments in the time series, i.e., the moment proportion, is calculated and set as the flowback flow abnormality. The higher the flowback flow abnormality, the greater the difference between the prediction and the actual monitoring, reflecting the greater the problem in the fracturing operation, and vice versa.

[0058] Next, when the abnormality of the return fluid flow is greater than or equal to the abnormality threshold, it is considered that the return fluid flow prediction time series information is inconsistent with the return fluid flow monitoring time series information, that is, it is considered that there is a significant difference between the prediction information and the monitoring information, and the prediction model needs to be re-evaluated.

[0059] Otherwise, when the abnormality of the discharge flow is less than the abnormality threshold, it means that the prediction time series information of the return flow is consistent with the monitoring time series information of the return flow, that is, the predicted return flow is consistent with the actual monitoring result, indicating that the prediction model has a high accuracy.

[0060] By comparing the time alignment, deviation calculation and anomaly evaluation of the backflow flow monitoring data and the predicted data, the matching degree between the predicted results and the actual monitoring can be effectively judged. When the difference between the prediction and the monitoring exceeds a certain threshold, it indicates that the inconsistency is higher and further optimization is needed; conversely, if the anomaly is lower, it means that the consistency between the prediction and the actual data is higher.

[0061] Furthermore, the present application also includes:

[0062] When the return fluid flow prediction timing information is inconsistent with the return fluid flow monitoring timing information, a balance abnormality signal is generated and sent to the user end.

[0063] Specifically, the following steps are performed by the balanced signal generation module. When the backflow fluid flow prediction timing information is inconsistent with the backflow fluid flow monitoring timing information, it means that there is a large deviation between the predicted backflow fluid flow and the actual monitored backflow fluid flow. The deviation may be due to inaccurate predictions or unexpected changes in the actual operation process, then the inconsistency will trigger the generation of abnormal signals. In order to cope with the generation of abnormal signals, a balanced abnormal signal is generated. The balanced abnormal signal indicates that the prediction of the backflow fluid flow does not match the actual situation, and it may be necessary to adjust the parameters of the fracturing operation or re-evaluate the prediction model. For example, if the difference between the monitored flow and the predicted value exceeds the set threshold, the abnormality is identified and the abnormal signal is automatically generated.

[0064] Subsequently, the generated balance abnormality signal will be sent to the user end, and the operator or relevant management personnel can receive this signal in time, so as to take necessary measures to correct the problem, adjust the operating parameters or optimize the model. For example, the user end receives a notification to remind that the flow prediction is inconsistent with the monitoring, and then checks whether there are abnormalities in key parameters such as construction pressure and fracturing fluid dosage.

[0065] By generating a balance abnormality signal, operators can be alerted in time to ensure that potential problems are discovered and resolved, thereby avoiding inaccuracies in operations that have an adverse impact on production.

[0066] Furthermore, the present application also includes:

[0067] When the backflow fluid flow prediction timing information is inconsistent with the backflow fluid flow monitoring timing information, the fracturing fluid dosage, the construction pressure, and the fracturing duration are updated to obtain the updated fracturing fluid dosage, the updated construction pressure, and the updated fracturing duration; the backflow fluid flow is predicted based on the updated fracturing fluid dosage, the updated construction pressure, the updated fracturing duration, the fracturing scenario parameters, and the fracturing fluid type to obtain the backflow fluid flow update prediction timing information; when the backflow fluid flow update prediction timing information is consistent with the backflow fluid flow monitoring timing information, the updated fracturing fluid dosage, the updated construction pressure, and the updated fracturing duration are added to the balance abnormality signal.

[0068] Specifically, the following steps are implemented by the balanced signal generation module and then fed back to the natural gas fracturing control parameter receiving module. When the flowback fluid flow prediction timing information is inconsistent with the flowback fluid flow monitoring timing information, the fracturing fluid dosage, construction pressure and fracturing time are updated to make the prediction results closer to the actual monitoring data. Assuming that the original fracturing fluid dosage is 1,000 cubic meters, the construction pressure is 60 MPa, and the fracturing time is 40 minutes, but due to the large deviation between the prediction and monitoring results, the fracturing fluid dosage is increased to 1,200 cubic meters, the construction pressure is increased to 70 MPa, and the fracturing time is extended to 50 minutes. The updated parameters can better reflect the needs in actual operations.

[0069] Next, based on the updated fracturing fluid usage, construction pressure, fracturing time, fracturing scenario parameters and fracturing fluid type, a new flowback fluid flow prediction is performed to obtain updated flowback fluid flow prediction time series information, making the prediction data more in line with the actual monitoring situation.

[0070] When the updated prediction time series information of the backflow flow is consistent with the monitoring time series information of the backflow flow, the updated fracturing fluid dosage, construction pressure and fracturing duration are added to the balance abnormality signal. For example, after adjustment, the predicted flow is completely consistent with the actual monitoring data, and then added to the abnormality detection system as a new operation signal to ensure that future operations can be carried out according to the optimized parameters.

[0071] The updated key parameters such as fracturing fluid dosage, construction pressure and fracturing time are added to the balance abnormality signal through the balance signal generation module, and then the prediction of the return fluid flow of this application is executed through the natural gas fracturing control parameter receiving module to determine whether the return fluid flow update prediction timing information is consistent with the actual monitored return fluid flow monitoring timing information, until a balance signal is generated when it is determined to be consistent, and the balance signal is sent to the user end.

[0072] By continuously adjusting the amount of fracturing fluid, construction pressure and fracturing duration, and predicting the flowback flow based on the updated parameters, the accuracy of the fracturing operation can be gradually optimized. When the prediction is consistent with the actual monitoring data, the updated parameters are formally adopted and used for subsequent operational decisions, ensuring that the prediction model is consistent with the actual operating conditions, thereby improving the efficiency and accuracy of natural gas fracturing operations.

[0073] In summary, the natural gas fracturing flowback fluid balance control system based on adaptive flow regulation provided by the present application has the following technical effects:

[0074] By receiving natural gas fracturing control parameters, wherein the natural gas fracturing control parameters include fracturing fluid dosage, construction pressure, fracturing time, fracturing scenario parameters, and fracturing fluid type; predicting the flowback fluid flow rate according to the fracturing fluid dosage, the construction pressure, the fracturing time, the fracturing scenario parameters, and the fracturing fluid type, and obtaining the flowback fluid flow prediction timing information; when the natural gas fracturing starts, obtaining the flowback fluid flow monitoring timing information; when the flowback fluid flow prediction timing information is consistent with the flowback fluid flow monitoring timing information, generating a balance signal and sending it to the user end, that is, by achieving the technical goal of natural gas fracturing flowback fluid balance control based on adaptive flow regulation, and then dynamically adjusting the flow prediction, ensuring that the prediction result is more in line with the actual situation, achieving the technical effect of improving the flowback fluid flow prediction accuracy and real-time adjustment capability, thereby optimizing the operation parameters and improving the efficiency and stability of the fracturing operation.

[0075] The above description of the disclosed embodiments enables those skilled in the art to implement or use the present application. Various modifications to these embodiments will be apparent to those skilled in the art, and the general principles defined herein may be implemented in other embodiments without departing from the spirit or scope of the present application. Therefore, the present application will not be limited to the embodiments shown herein, but will conform to the widest scope consistent with the principles and novel features disclosed herein.

[0076] Obviously, those skilled in the art can make various changes and modifications to the present application without departing from the spirit and scope of the present application. Thus, if these modifications and variations of the present application belong to the scope of the present application and its equivalent technology, the present application is also intended to include these modifications and variations.

Claims

1. A natural gas fracturing flowback fluid balance control system based on adaptive flow regulation, characterized in that: include: A natural gas fracturing control parameter receiving module, which is used to receive natural gas fracturing control parameters, wherein the natural gas fracturing control parameters include fracturing fluid dosage, construction pressure, fracturing time, fracturing scenario parameters, and fracturing fluid type; A flowback fluid flow prediction timing information acquisition module, the flowback fluid flow prediction timing information acquisition module is used to predict the flowback fluid flow according to the fracturing fluid dosage, the construction pressure, the fracturing duration, the fracturing scenario parameters, and the fracturing fluid type, and obtain the flowback fluid flow prediction timing information; A flowback fluid flow monitoring timing information acquisition module, wherein the flowback fluid flow monitoring timing information acquisition module is used to obtain the flowback fluid flow monitoring timing information when natural gas fracturing begins; A balance signal generating module, wherein the balance signal generating module is used to generate a balance signal and send it to a user end when the backflow liquid flow prediction timing information is consistent with the backflow liquid flow monitoring timing information; The flowback fluid flow prediction is performed according to the fracturing fluid dosage, the construction pressure, the fracturing time, the fracturing scenario parameters, and the fracturing fluid type to obtain the flowback fluid flow prediction time series information, including: A first constraint condition is constructed according to the amount of fracturing fluid, the construction pressure, the fracturing time, and the fracturing scenario parameters. Specifically, the amount of fracturing fluid is 500 cubic meters, the construction pressure is 50 MPa, the fracturing time is 30 minutes, and the formation permeability in the fracturing scenario parameters is 0.02 Darcy and the porosity is 12%; According to the type of fracturing fluid, a second constraint condition is constructed. Specifically, different fracturing fluids are selected according to the performance of the fracturing fluid and the characteristics of the formation. Among them, the linear glue has a low viscosity and is suitable for low permeability formations, and the cross-linked glue improves the support capacity of the fracture through high viscosity; Based on the first constraint condition and the second constraint condition, natural gas fracturing samples meeting the constraint conditions are screened, and natural gas fracturing samples without abnormalities are collected by recording and collating various parameters and results in actual construction, including crack formation under different fracturing fluid dosages and pressure conditions, to obtain a natural gas fracturing sample set; The natural gas fracturing sample set includes a flowback fluid flow record time series tag set; A mode analysis is performed on the time series tag set of the return fluid flow record to obtain the return fluid flow prediction time series information.

2. The natural gas fracturing flowback fluid balance control system based on adaptive flow regulation as claimed in claim 1, characterized in that: Based on the first constraint condition and the second constraint condition, natural gas fracturing samples without abnormality are collected to obtain a natural gas fracturing sample set, including: Based on the first constraint condition and the second constraint condition, natural gas fracturing samples without abnormality are collected to obtain a first-level natural gas fracturing sample set, wherein any first-level natural gas fracturing sample has a fracturing fluid dosage label, a construction pressure label, a fracturing duration label, and a fracturing scenario parameter label; Constructing a third constraint condition according to the fracturing fluid dosage label, the construction pressure label, the fracturing duration label, and the fracturing scenario parameter label; Based on the second constraint condition and the third constraint condition, natural gas fracturing samples without abnormality are collected to obtain a secondary natural gas fracturing sample set; The analysis is repeated until a set of N-level natural gas fracturing samples is obtained; The first-level natural gas fracturing sample set, the second-level natural gas fracturing sample set, and finally the N-level natural gas fracturing sample set are added into the natural gas fracturing sample set.

3. The natural gas fracturing flowback fluid balance control system based on adaptive flow regulation as claimed in claim 2, characterized in that: Based on the first constraint condition and the second constraint condition, natural gas fracturing samples without abnormality are collected to obtain a first-level natural gas fracturing sample set, including: Obtaining a natural gas fracturing sample with no abnormality to be selected, wherein the natural gas fracturing sample with no abnormality to be selected has a fracturing fluid type label to be selected, a fracturing fluid dosage label to be selected, a construction pressure label to be selected, a fracturing time label to be selected, and a fracturing scenario parameter label to be selected; When the candidate fracturing fluid type label satisfies the second constraint condition, and the candidate fracturing fluid usage label, the candidate construction pressure label, the candidate fracturing duration label, and the candidate fracturing scenario parameter label meet the first constraint condition, the candidate natural gas fracturing normal sample is added to the first-level natural gas fracturing sample set.

4. The natural gas fracturing flowback fluid balance control system based on adaptive flow regulation as claimed in claim 3, characterized in that: Also includes: When the to-be-selected fracturing fluid type label is the same as the fracturing fluid type, it is deemed that the to-be-selected fracturing fluid type label satisfies the second constraint condition; When the first deviation between the to-be-selected fracturing fluid usage label and the fracturing fluid usage is less than or equal to the first deviation threshold, and the second deviation between the to-be-selected construction pressure label and the construction pressure is less than or equal to the second deviation threshold, and the third deviation between the to-be-selected fracturing duration label and the fracturing duration is less than or equal to the third deviation threshold, and the fourth deviation between the to-be-selected fracturing scenario parameter label and the fracturing scenario is less than or equal to the fourth deviation threshold, the to-be-selected fracturing fluid usage label, the to-be-selected construction pressure label, the to-be-selected fracturing duration label, and the to-be-selected fracturing scenario parameter label are deemed to satisfy the first constraint condition.

5. The natural gas fracturing flowback fluid balance control system based on adaptive flow regulation as claimed in claim 1, characterized in that: When the flowback fluid flow prediction timing information is consistent with the flowback fluid flow monitoring timing information, it includes: Aligning the start time of the backflow fluid flow monitoring timing information with the backflow fluid flow prediction timing information, intercepting the backflow fluid flow prediction timing information, and obtaining the backflow fluid intercepted flow prediction timing information; Counting the deviation time series information of the flowback fluid interception flow prediction time series information and the flowback fluid flow monitoring time series information; Counting the proportion of moments in which the backflow liquid flow deviation in the backflow liquid flow deviation time series information is greater than or equal to the backflow liquid flow deviation threshold, and setting it as the backflow liquid flow abnormality; When the abnormality of the backflow fluid flow is greater than or equal to the abnormality threshold, it is considered that the backflow fluid flow prediction time series information is inconsistent with the backflow fluid flow monitoring time series information; Otherwise, it is deemed that the return fluid flow prediction timing information is consistent with the return fluid flow monitoring timing information.

6. The natural gas fracturing flowback fluid balance control system based on adaptive flow regulation as claimed in claim 1, characterized in that: Also includes: When the return fluid flow prediction timing information is inconsistent with the return fluid flow monitoring timing information, a balance abnormality signal is generated and sent to the user end.

7. The natural gas fracturing flowback fluid balance control system based on adaptive flow regulation as claimed in claim 6, characterized in that: When the backflow liquid flow prediction timing information is inconsistent with the backflow liquid flow monitoring timing information, a balance abnormality signal is generated and sent to the user end, further comprising: When the flowback fluid flow prediction time series information is inconsistent with the flowback fluid flow monitoring time series information, the fracturing fluid dosage, the construction pressure, and the fracturing duration are updated to obtain the updated fracturing fluid dosage, the updated construction pressure, and the updated fracturing duration; Based on the fracturing fluid update dosage, the construction update pressure, the fracturing update duration, the fracturing scenario parameters, and the fracturing fluid type, the flowback fluid flow rate is predicted to obtain the flowback fluid flow rate update prediction time series information; When the backflow fluid flow rate update prediction timing information is consistent with the backflow fluid flow rate monitoring timing information, the fracturing fluid update amount, the construction update pressure, and the fracturing update duration are added to the balance abnormality signal.

Images